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Home My WebLink About176-009a^~ . ~ ~ ~ ~~ ~ ® ~~~ ~ ~~ ~ ~~ g {~ p gg [~c~9 ~ yy ¢ a c ® ® / ~y[~~n {fig ~} ~L~~C ®jtle Y39 i7~ 6>I6'tl~ 4~®@~~~1`d ll6~ I'®N ~®~WikV91 7 3B®1~1' ~Jy~ ~ a +, / i I ~ ~ 201 . ~~ - 1a. Well Status: Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ ib. Well Class: 20AAC 25.105 20AAC 25.110 ~'~ Development ^ Expf~f~ ~~dSStf)!~ GINJ^ WIND ^ WDSPL^ WAG ^ Other^ No. of Completions: 1 Service ^ Stratigraphic Test[] 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: BP Exploration (Alaska) Inc. Aband.:~/a~1,?~~~ 176-009 3. Address: 6. Date Spudded: 3, 13. API Number: P.O. Box 196612 Anchorage, Alaska 99519-6612 3/8(1976 t~ 50-029-20192 ~ I 3~ `-Qa 4a. Location of Well (Governmental Section): Surface: 1742' NSL 744' EWL S 23 T IIN R 7. Date TD Reached: 14. Well Name and Number: , , ec. , . ., . 12E.,UM 5/9/1976 Kuparuk 22-11-12 Top of Productive Horizon: 8. KB (ft above MSL): 64 ft. 15. Field/Pool(s): 3089' NSL, 2286' W EL, Sec. 22, T.IIN.,R. 12E., UM Ground (ft MSL): 38 ft. Prudhoe Bay Tota{ Depth: 9. Plug Back Depth(MD+TVD): 3134' NSL, 2387' WEL, Sec. 22, T. IIN., R. 12E., UM Surface 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Properly Designation: Surface: x- 615, 302 y- 5, 956, 650 Zone- 4 ~ 10192 MD, 9192 TVD ' ADL47451(Surface)ADL28263 (B.H.) TPI: x- 612, 272 y- 5, 957, 997 Zone- 4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 612, 171 y- 5, 958, 042 Zone- 4 None DNR / NSB 18. Directional Survey: Yes ~ No 19. Water Depth, if Offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1950 ft. 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): CBLNOUCCUGR. Spectralog, TDT, gradio -all previously submitted 22• CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT FT. TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED Cond. 156# LP Surface 71' Surface 71' 36" 125 sx permafrost None Surf. 94# H-40 Surface 735' Surface 735' 26" 4000 sx permafrost None Int. 72# N-80 Surface 2723' Surface 2723' 171/2" 5000 sx permafrost None Prod. 29# Soo-95 Surface 10,172' Surface 9173' 8 1/2" 500 sx Class G None Open to production or injection? Yes ^ No ^ If Yes, list nral open (MD+TVD of Top & Bottom; Perforation Size and Number): ~~~A~,~C3 NOV 0 ~ 2007 ~• TUBING RECORD SIZE DEPTH SET (MD) PACKER SET 4 1 /2" 9657' 9579' ~. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL fee attached for description of ® P&A squeeze work Form 10-407 Revised 2/2007 ~ ~ t ~ ~ ~ ~ NTINUED ®N REVERSE • 28. GEOLOGIC MARIZERS (Lisfi all r`ormations and markers encountered): 29. FORMATION TESTS NAME M® TV® Well tested? Yes No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this forrn, if Permafrost -Top 4' 4' needed, and submit detailed test information per 20 AAC 25.071. Permafrost -Base 1950' 1950' See previous Completion Reports Formation at total depth: ®n file at A®GCC 30. List of Attachments: - - ~~~liy k"'„;t;Cark~s' £.;i' i~c' ~~p~k'2i9.i~34"1~., ,`'~'G~7C-.n"d=.ti~ ~ ~- ;a' nf~~, ~17C.3r~;i ta_rarit. I`~~s<^srla i ~l 31. I hereby certify that the foregoing is true and correct to the best of my Knowledge. Cantact: Printed Name: Douglas A. Cismoski Title: Wells Team Leader, Alaska Drilling and wells Phone: 907-564-4303 Date: 4118~'~AA~ IfVSI'RUCTiONS 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: 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 and Ground Level elevations in feet above mean sea level. 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: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Iierc~ 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: ff this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 sFiow 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). Bern 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a listing of inten+als tested and the corresponding formation, and a brief summary in this boat. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Fornr 10-407 Revised 2!2007 • RECORD OF PLUGGING AND ABANDONMENT OPERATIONS BP Exploration (Alaska) Inc. Kuparuk 22-11-12 PTD: 176 - 069 API No. 50-029-20192 Introduction and Background Kuparuk 22-11-12 was drilled in 1976 by Mobil Oil Corporation as an exploration well. It was logged and tested prior to being suspended in May of the same year. Standard Alaska Production Company (now BP Exploration (Alaska) Inc., became the operator of the well in 1980, and recompleted the well as a pressure observation well for the western side of the Prudhoe Bay Unit. Prior to the P&A work described below, the well had been suspended for several years. The well was originally located on a gravel pad which was reached by a gravel road from "W"pad. The pad and connecting road were removed after the well was permanently abandoned as part of on going remediation work being carried out by BPXA within the Prudhoe Bay Unit. The P&A operations recorded below were hampered by several periods of Phase II and III weather conditions which prolonged the abandonment effort. The well was permanently abandoned on March 19, 2007, and the casing strings are cut off and capped with a marker plate four (4) ft. below the original tundra surface (see attachments I, II, and III). All critical components of the P&A work were inspected and approved by AOGCC representatives. P&A Operation Summary January 17-22, 2007: Cleared snow from pad. Constructed ice road for vehicular access to pad. Installed wellhead shelter, and applied heat to wellhead. Coordinate equipment needs with service company and operator. January 23, 2007: Rigged up hot oil unit and thawed well. Serviced valves on wellhead. January 24 -27, 2007: Moved in tanks and support equipment. Rigged up slickline and pulled T-check from X-nipple at 1991 ft. made dummy slickline run to PBTD. No obstructions. Waited on availability of coiled tubing unit. January 28-30, 2007: Rigged up coiled tubing unit to squeeze perfs. Established positive wellhead pressure with methanol followed by water. Tagged TD and positioned nozzle to squeeze perfs with 25 bbls class G. Squeezed cement away until TOC @ below 9000 ft. in tubing. WOC 24 hours. January 31 -February 2, 2007: Operations shut down by weather. Ice road to pad closed by drifting snow. February 3, 2007: Re-opened ice road to pad. Rigged up slickline unit for drift to TOC. 480 psi initial pressure on tubing and 60 psi on IA. Pressured up tubing to 1550 psi with 0.7 bbls methanol. IA pressure increased to 150 psi in 15 minutes and to 200 psi in 30 • • minutes. Bled pressures, pulled tree cap, stabbed onto well and pressure tested lubricator 300 psi low/2500 psi high. Drifted well to TOC @ 9168' February 4, 2007: Rigged down slickline and bled off tubing to 100 psi. Rigged up to pressure test tubing and IA. Pumped 2 bbls methanol into IA to reach test pressure of 1500 psi. Tubing pressure rose to 1520 psi. Extended test out to 45 minutes. Test pressures at end of test: Tubing - 1580 psi, IA - 1485 psi, OA- 0 psi. Test witnessed by AOGCC inspector John Crisp. Bled off test pressures. MIRU wireline unit for tubing punch. Tested lubricator to 3000psi. RIH with tubing punch and punched tubing 8800 - 8805 ft. POH with tubing punch. February 5, 2007: Equalized tubing and IA with kill weight NaCI. Thermal expansion caused OA flange to leak arctic pack. Repaired flange. Made up jet cutter for tubing cut. RIH and cut tubing at 300 ft. POH with spent cutter. Monitored and bled IA and OA as annuli temperatures equalized. February 6, 2007: Continued to monitor pressures. Pressure very low (0-3psi) and intermittent as downhole annular temperatures equalized. Tubing, IA, and OA pressures at zero at end of day. February 7, 2007: Wellsite operation suspended due to weather. High winds/blowing snow. February 8, 2007: Continuing to bleed very low pressure residual gas from tubing and IA. Rigged up rinohide tent around tubing hanger and applied heat in preparation to pull cutoff tubing. All pressures at zero at end of day. February 9, 2007: Continuing to bleed residual gas from tubing and IA. Maintained open bleed for 24 hours. All pressures at zero. February 10, 2007: Tubing and IA at zero. Sniff of tubing revealed an LEL above allowable levels. Purged tubing with nitrogen and took returns out the IA to tank. Pressure at end of nitrogen purge: Tubing - 0, IA -vacuum, OA - 0. February 11, 2007: Continue to observe well. Move in equipment to pull and lay down tubing. February 12, 2007: Remove production tree. Unseat tubing hanger, pull and lay down tubing. Install dry tree. February 13, 2007: Moved in equipment to circulate arctic pack out of 7" x 13 3/8" annulus (OA). Rigged up wireline unit and set CIBP in 7" casing at 240 ft. Perforated 7" casing at 235 ft. to access arctic pack. Rigged down wireline unit and rigged up reverse out skid and hot oil unit to circulate arctic pack out of 7" x 13 318" annulus. • February 14, 2007: Circulated arctic pack out of 7" x 13 3/8" annulus with hot oil unit using alternating circulations down the annulus and up the casing, and then down the casing and up the annulus. Moved out hot oil unit and moved in cementing equipment to set top plugs. February 15, 2007: Set top cement plugs in 7" casing and in 7" x 13 3/8" annulus. Surface plug in 7" @ 0' - 240', and in annulus at 0' - 235'. Plugs witnessed and approved by AOGCC inspector. Well awaiting subsurface cut-off and marker plate installation following gravel remediation work on pad. February 16 -March 6, 2007: Gravel pad remediation work, including numerous weather delays. March 7, 2007: Excavated around well to approximately 6 ft below original tundra surface. Moved in crane for wellhead removal after cut. March 8 -March 12, 2007: Waiting on weather Phase II and III conditions. March 13, 2007: Hot tapped 30" x 20" annulus in preparation for cut - no cement. Continued tap into 20" x 13 3/8" annulus and encountered diesel. Contained and cleaned up %i gal diesel spill. Secured operations and waited on orders. March 14 -15 2047: Wait on weather. High winds and blowing snow. March 16, 2007: Spot equipment on pad, rig up Wachts saw and prepare to cut off wellhead. March 17, 2007: Cut off wellhead = Sft. below original Tundra surface. AOGCC inspector witnessed cut, and removal of wellhead. Top job on cement required in 20" x 13 3/8" annulus. March 18, 2007: Completed top job and received approval from AOGCC inspector to install subsurface marker plate. March 19, 2007: Installed subsurface marker plate and backfilled excavation to original tundra surface. Left small mound over excavation to allow for future settlement. • c: Post Abandonment Wellbore Schematic BP Exploration(Alaska) Inc. Kuparuk 22-11-12 PTD: 176-009 API No.: 50-029-20192 No Scale Original Tundra Surface >4' Legend Cement ;~;~;~; Arctic Pack, 10.2 ppg ® 9.6 ppg brine Subsurface marker plate s 30° conductor @ 71ft. '' ~' '" Top plug @240 ft. ~~ ,~ r Tubing cut @ 300 ft. ~' '~ '~ ~' ~' ~ ~- 20" 94# H-40 @ 735 ft. ~; ,, ~, ,, ~, ,, ~' ~' , ~' , ,~ ,~ ~' , FO Collar @ 2,257 ft. __ _ 13-3/8" 72# N-80 @ 2,723 ft. TOC in Tubing @ 9,168ft. Production packer @ 9,579 ft. Tubing Tail @ 9,657 ft. Peru @ 9,832'-9,845'(squeezed) Perfs @ 9,862'-9,892'(squeezed) Perfs @ 9,910'-9,935'(squeezed) 7" 29# S-95 @ 10,172 ft. TD @ 10,192 ft. • .. .. . `~, .~'~ k ~,, ~~ ~"'~. Y4 J ~ i ~ f '~ 4 J. ^ # J ~' - .~,' ~ Ya .~ s+~ ~~ 4,• ~~~ '~ M ~~ .~ T .'j~k, _ , ~~ , . a,;. * :~ ~~ ~ E _~,~ ' ~ g'a' ~ . ': ~r r' ; .. ~ ' , . r ~, y r ~ '' .. e k I e, i s. Data P1~~~ i~~F~ _ ~ ~~ ~ ' . Cemented (top job) of 22-11-12 • „F~:: ~~' ~ x~ ~EF ~A ~'^+~~ ~~~ ~~ • _{~ ~ r Y ' = ~,,~ e '~ Lid . ~ ~ *..: ~~:~ ~: _./ ~, -9~ i ~~ _~i S :~ - ,~ -~,~ ~, k ~' ! NN. ~~' ' ~ _~~~ .~` x.' _, ~.. .. , Plate installed for 22-ll-12 y~~ W ~. ~ „~ ~iF ~e`,~ ~ -+~ ',~ M ~ ~~~ i ` ~~ ~., q ~t ~' At .. .4 ;x~ 4 / ~~ y ~ ~4. ~~ yy ~g ,fY..I ) i k ~ 1. ~ ~ :>. ~~ ,. ~..`}' • i sn ~ • ~ " t ~~ .- ~~ _ ~tci~ r G ~~ :, Day after install waiting on final soil sample??-l 1-1? Page 1 of 1 Maunder, Thomas E (DQA) From: Cismoski, Doug A [CismosDA@BP.comj Sent: Tuesday, September 25, 2007 11:06 AM To: Maunder, Thomas E (DOA); Bob Gardner ~~r ,_O~~ Cc: Roby, David S (DOA); Davies, Stephen F (DOA) V~ Subject: RE: Kuparuk 22-11-12 (176-009 Tom - Several Sundries were signed by me yesterday and today. They should be out the door this afternoon to your office. Doug From: Maunder, Thomas E (DOA) [mailto:tom.maunder@afaska.gov] Sent: Thursday, September 06, 2007 10:12 AM To: Bob Gardner; Cismoski, Doug A Cc: David S. Roby; Stephen F Davies Subject: Kuparuk 22-11-12 (176-009 Bob and Doug, I was clearing out some old messages and looked at our file for this weN. There is no 407 in the fife and I do not find any entry in the incoming document log for items received. According to the. Inspectors' reports in the fete, the cutoff was witnessed on March 18. The 407 was due 30 days later. The 407 with attachments should be submitted not later than September 30. Thanks in advance for your attention to this matter. Catl or message with any questions. Tom Maunder, PE ~ ^-^"~""""'"'~'~~"" AOGCC ~,;~,~~~}~~ NOV Q $ 2007 ioi12i2oo~ . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: ,":} zJ1;7lò 7 Jim Regg, ~æø¡q -1 DATE: P. I. Supervisor March 19, 2007 FROM: Jeff Jones SUBJECT: Petroleum Inspector Surface Abandonment Kuparuk 22-11-12 BPXA PTD #176-009 March 18,2007: I traveled to BPXA's Kuparuk 22-11-12 well location to inspect the casing cut off and surface abandonment of this well. I verified that all casing strings had "been cut off at least 5 feet below original grade. A small amount of what appeared to be'diesel contaminated mud was visible in the 7" X 13 3/8" annulus and I instructed BPXA representative Andy Hedinger to remove this material and top off the annuli with additional cement. I returned to this location on 3/19/07 and verified that aiL casing annuli were full of cement and the 30" diameter, 3/4" thick marker plate with the required information bead welded to it was then seal welded to the outermost conductor pipe. Summary: I inspected the surface cement plug, casing cut..ifæ!7th, ëíllc.1~me Þ&7X marker plate on BPXA's Kuparuk 22-11-12 well and verified that all were in compliance with AOGCC regulation 20 AAC 25.120. Attachments: Photos (2) SCANNED APR 0 5 Z007 X Unclassified Classified ._- ,.......- Unclassified with Document Removed . . Kupafuk 22-11-12 (BPXA) Surface Abandonment Inspection Photos from Jeff Jones, AOGCC March 18, 2007 Casing cutoff; cement to surface; marker plate Installing marker plate MEMORANDUM . State of Alaska . c\laska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ~erq 3/7/D 7 DATE: Monday, March 05, 2007 SOBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 22·11·12 KUPARUK 22·11·12 FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P. I. Suprv ::T"i3.e- Comm NON-CONFIDENTIAL Permit Number: 176-009-0 Inspector Name: John Crisp Inspection Date: 2/4/2007 Well Name: KUPARUK 22-11·12 Insp Num: mitJCr070305091712 ReI Insp Num API Well Number 50-029·20192-00-00 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. _u_ .,__.___.'n._ ---·-----;-'.~_I._ Well 22-11·]2 ¡Type Inj. N TVD ------_._--_.~-~_.+ P. T. 1760090___Type~est_S~T_ Test~~!_ . - . -----~---- ,- --- -----,,-"----- -----,~----_.._---_._---- -. -- ~----~-- ._-~--_._-_.- 8300 IA --. - --'-- ,..-----.- 2075 OA o 1550 1540 1490 ]485 o ______'om. ._____._~ o o Iºt~ryª-I OTHER PIF - ----_.,-------~----_.__. ,- P Tubing ]70 1590 1580 1580 J 580 - .~.__.._--- Notes Pressure test performed with tubing &!A in communication. VerifY cement plug for P&A @ 8300' 2 bbl's pumped for PT. ù bse.V'¿~~ ~ sCANNED MAR 2 7 2007 Monday, March 05, 2007 Page 1 of I RE: FW: Scan ITom a Xerox WorkCentre Pro e e Tom: \"'\<0 -00,\ I believe it will be at least 10 days, if not longer, before BP is ready to deal with these wells. If I hear anything more definitive I'll let you know. Regards, Bob -----Original Message----- From: Thomas Maunder [0ë.'~~~(?:.t::?~11_~9:'!.rlqEè1:(¡j)_é1c:ì~~n. state. ak. us] Sent: Friday, February 16, 2007 3:01 PM To: Bob Gardner Subject: Re: FW: Scan from a Xerox WorkCentre Pro Bob, The revisions look good. Any idea when the work might take place? Tom Bob Gardner wrote, On 2/16/2007 1:29 PM: Hello Tom: At long last here are the revised procedures for the Tract wells which describe the steps for the arctic pack flush. Please advise if you have any questions. Thanks, Bob scANNED FEB 2 0 Z007 -----Original Message----- From: Xerox3545@fairweather.com Ito:Xerox3545@fairweather. ..·....._..···.._·..··_.....··....._.._·...........·.........··."mm....··......._.__.._........._.._..~.._._ Sent: Friday, February 16, 2007 12: 8 PM To: Bob Gardner Subject: Scan from a Xerox WorkCentre Pro Please open the attached document. It was scanned and sent to you using a Xerox WorkCentre Pro. Sent by: Guest [.li:<:::~:'?~~?~?«j)~_0::tEÍ^l_~.0:~}:"'E:c:;?0] Number of Images: 9 Attachment File Type: PDF WorkCentre Pro Location: Fairweather Inc Device Name: Xerox3545 For more information on Xerox products and solutions, please visit . xero:x ~ com 1 of 1 2/16/2007 3: 14 PM Re: Kuparuk 22-11-12 e e Doug, I got your message. I agree that there are some issues to sort out prior to punching or cutting. What you propose with regard to removing the diesel from the well should work. Thanks for addressing these matters. Call or message with any questions. Tom Maunder, PE AOGCC Cismoski, Doug A wrote, On 2/2/200712:52 PM: Tom - We need to verify we have T x IA comm. This wasn't clearly defined but there is evidence that leads us to believe that the MIT-IA done early on may have been against an ice plug in the annulus. We'll know more during the upcoming pressure tests and will keep you updated. I left you a message on your voicemail, but we can shoot holes below 500' MD in the 4-1/2" tubing to circulate out the diesel if the communication isn't existent or sufficient. We will do what we can to ensure the diesel is removed. I'm waiting on a developing another revised plan until we can confirm the mechanical integrity of the tubing. My goal is to ensure we have a clear understanding of the well's mechanical condition before proceding with any further punches or cutting the tubing. Doug -----Original Message----- From: Thomas Maunder Sent: Friday, February To: Cismoski, Doug A Cc: Lou Grimaldi; Bob Gardner Subject: Re: Kuparuk 22-11-12 maunder@admin.state.ak. 10:53 AM Doug, Thanks for responding. You are correct on the regulatory reference. What you propose looks acceptable, with one note. In the last years it has been the practice not to leave diesel in wells if at all possible. I went back and looked at the original proposal and I see where diesel was proposed in the displacement fluid to avoid it running away. I missed that the diesel would be left in the tubing. Do you have any indication of where the tubing might be communicating to the annulus? It may be that you have to tag the plug which is acceptable. Is the communication path sufficient to reverse the diesel out of the tubing? Call or message with any questions. Tom Maunder, PE AOGCC Cismoski, Doug A wrote, On 2/2/2007 10:37 AM: lof4 2/16/20072:32 PM Re: Kuparuk 22-11-12 e e \~<O-(Ja~ Tom - This is the text I believe is from the same code you referenced below. . (f) Each of the respective intervals of a wellbore between the various plugs must be filled with fluid of sufficient density to exert a hydrostatic pressure exceeding the greatest formation pressure of permeable formations in the intervals between the plugs at the time of abandonment. During wireline operations on January 24, 2007, the static pressure was recorded at MD 10,065 9850 9660 the following SS 9024 8846 8690 stations. . . BHP 3720 3643 3573 This works out to an equivalent density of 7.9 ppg The current liquids left in the tubing after the plugging of the perforations is MD SS Density Gradient Fluid Type 0 - 500' 436 6.8 0.354 psi/ft Diesel 500 - 2200' 2136 7.6 0.393 psi/ft 60/40 methanol water 2200 - 9183' 8301 8.5 0.441 psi/ft Seawater During the plugging operation we discovered tubing by inner annulus communication and this discovery is currently affecting pressure test results. We had to abort the pressure testing because of weather conditions and snow removal. Once conditions permit, we'll resume pressure testing the cement plug. After a successful pressure test and tag of cement top (we estimate at 9183'), our current plan is to cut the tubing between 250 and 300' and set a bridge plug at 210'. This is not indicated on the well schematic included with the sundry application. I believe the breakdown may have been in my communication with Bob Gardner. I estimate the BHP at 8301' SS to be 3413 psi (based on the measured 7.9 ppg gradient). The current hydrostatic at 8301'SS (above the cement plug) is 3541 psi which I believe satisfies the State code copied above. 2of4 2/16/20072:32 PM Re: Kuparuk 22-11-12 e e I'm requesting the State's approval on leaving the existing liquid in the tubing string. \ "( <0-00 '\ The remaining work is: * to cut the 4-1/2" tubing between 250 and 300', remove tubing, set 7" bridge plug at -220' and punch 7" casing at * * -210' , * * at 210' to * circulate out the arctic pack in the 7 x 13" annulus, Cement 7" casing and 7 x 13" annulus from casing holes surface. The rest of the work was listed in the original sundry application. If approved, I would like Bob to submit a revised program calrifying cut depths, arctic pack circulation, etc. for your records upon his return next week. Doug Cismoski, P.E. Wells Team Leader Alaska Drilling and Wells iginal Message----- From: Tn s Maunder [11!9:jl.t:?:_~gTIl..-nla1?:;~c:lEèE«j)éic:ì~t:liIl. state. ak .us] Sent: Thurs January 25, 2007 4:36 PM To: Bob Gardner Cc: Cismoski, Doug A, ou Subject: Re: FW: Kuparuk and Doug, other item upcoming on this well. As noted 'n our conversations, the reported surfaqø/pressure suspect due to th age of the well and unknowns regard~øg the reliability of the age and the condition of the T c~ék. The actual well pressure should e accurately known as the wor~proceeds. The present weight of luid reported in the annulµ§ is 9.6 ppg (if I read the drawing correc Leaving this fluid/in the well is according 30f4 is sufficient to overbalance the reser ir pressure. See 2 Call or mes ge with any questions. , PE wrote, On 1/24/2007 9:41 AM: Morning, Tom >Here are the revisions to 22-11-12. 2/16/20072:32 PM f\.Ç". or r<.x..¡-\. 21 e e Subject: Re: B From: Thoma Date: Fri, 02 To: Ism Doug, Any update on the P&A work? Also, I will need a revision regarding the procedure to attempt to remove the arctic pack from the depth of the surface plug. Call or message with any questions. Tom Maunder, PE AOGCC Thomas Maunder wrote, On 1/30/2007 1 :49 PM: Thanks Doug. I've been out myself. Talk to you later. Cismoski, Doug A wrote, On 1/30/2007 10:28 AM: I'm stepping out the door but I don't know the exact timing of the P&A's. ! have a question in to the pad remediation manager for an update. 1 of 1 2/2/20077:55 AM Re: FW: Kuparuk22-11-12 e e Bob and Doug, \ ~ <0 -0 a ~ One other item has "surfaced" with regard to the upcoming work on this well. As noted in our conversations, the reported surface pressure is suspect due to the age of the well and unknowns regarding the reliability of the gage and the condition of the T check. The actual well pressure should be accurately known as the work proceeds. The present weight of fluid reported in the annulus is 9.6 ppg (if I read the drawing correct). Leaving this fluid in the well is according to the regulations so long as the hydrostatic pressure is sufficient to overbalance the reservoir pressure. See 20 AAC 25.112 (f). Call or message with any questions. Tom Maunder, PE AOGCC Bob Gardner wrote, On 1/24/2007 9:41 AM: Good Morning, Tom Here are the revisions to 22-11-12. I went ahead and fixed a couple of typos in the first section as well, hence you have a completely new submittal to replace the one that was attached to the Sundry. I don't think any changes are required on the Sundry. Thanks for you help with this. Give a call if you have any questions. Regards, Bob -----Original Message----- From: :ï{~E_c:J~_~?~?i!!ì~?:iE~C::0:_t;her. com [~9:~:1.:.t::?:.li:~Ec:J.::<:3?_:~?~~.0:.~~~'J\/r::9:t;þ<:::E~<:;c:J~] Sent: Wednesday, January 24, 2007 10:43 AM To: Bob Gardner Subject: Scan from a Xerox WorkCentre Pro Please open the attached document. a Xerox WorkCentre Pro. It was scanned and sent to you using Sent by: Guest [Xerox3545@fairweather.com] Number of Images: 8 Attachment File Type: PDF WorkCentre Pro Location: Fairweather Inc Device Name: Xerox3545 For more on Xerox products and solutions, please visit 1 of 1 2/16/20072:32 PM . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 'Kt?11 t-/6 (D7 DATE: February 4, 2007 P. I. Supervisor FROM: John Crisp, Petroleum Inspector SUBJECT: Casing Pressure Test Kuparuk 22-11-12 BPX PTO 176-009 February 4.2007: I traveled to BP's Kuparuk 22-11-12 off PBU W Pad to witness the cement plug-casing test for P&A. Pressure test required verifying integrity of cement plug in tubing & IA. Tested production casing to 1500 psi. Pressure test performed with IA & tubing in communication. Pressures found. Tubing '170 psi. IA 0 psi. OA 0 psi. Initial Test pressure. Pumped 2 bbl's for test. Tubing 1590 psi. IA 1550 psi. OA 0 15 minute test. Tubing 1580 psi. IA 1540 psi. OA 0 psi. 30 minute tesLTubing 1580 psi. IA 1490 psi. OA 0 psi. 45 minute test. Tubing 1580 psi. IA 1485 psi. OA 0 psi. Summary: I witnessed a successful pressure test of cement plug & casing allowing BP to continue operations to perform surface P&A onwell Kuparuk 22- 11-12. ¿//O. Attachments: Photo's of tree & well site. Non-Confidential ~tANNED FEB 2 7 2007 Casing pressure test Kuparuk 22-11-12 02-03-07 jc.doc . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg~eczc¡ ¿¡b/o7 DATE: P. I. Supervisor February 3, 2007 FROM: John Crisp, SUBJECT: Petroleum Inspector Cement Plug Tag Kuparuk 22-11-12 BPX PTO 176-009 February 3.2007: I traveled to BP's Kuparuk 22-11-12 off PBU W Pad to witness the wire line tag of cement plug inside the 4.5" tubing. Perforations on this well were from 9832' to 9935'. Production packer set in 7" casing @ 9579'. Cement was squeezed thru tubing into perf's below production packer calculated to leave cement top in tubing @ 9200'. ,/ I witnessed WL lubricator R/U to tubing & tested to 2500 psi. 1.25" bailer was run on WL to MO of 9168' where TOC was found for verification of plug. IA pressure test was aborted due to equipment problems. ...,/ Summary: Wire Line tagged cement plug inside 4.5" tubing @ 9168' on well Kuparuk 22-11-12 Attachments: Photo's of tree & well site. Non-Confidential iCANNED FES 2 7 2007 Cement Plug Tag Kuparuk 22-11-1202·03-07 jc.doc . . SARAH PALIN, GOVERNOR A.IJA.~1iA. OIL AlO) GAS CONSERVATION COMMISSION Douglas Cismoski Wells Team Leader BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 SCANNED JAN 252007 ..... .. ·hh". 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 _. Re: Prudhoe Bay Field, Exploration, Kuparuk 22-11-12 Sundry Number: 307-027 \1bJ f)Ö~ Dear Cismoski: 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 me 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, Encl. FW: Scan from a Xerox WorkCentre Pro . . Good Morning, Tom Here are the revisions to 22-11-12. I went ahead and fixed a couple of typos in the first section as well, hence you have a completely new submittal to replace the one that was attached to the Sundry. I don't think any changes are required on the Sundry. Thanks for you help with this. Give a call if you have any questions. Regards, Bob -----Original Message----- From: Xerox3545@fairweather.com [mailto:Xerox3545@fairweather.com] Sent: Wednesday, January 24, 2007 10:43 AM To: Bob Gardner Subject: Scan from a Xerox WorkCentre Pro Please open the attached document. It was scanned and sent to you using a Xerox WorkCentre Pro. Sent by: Guest [Xerox3545@fairweather.com] Number of Images ~_.màm.._.mmm....mmmmm_.mmmmmm Attachment File Type: PDF WorkCentre Pro Location: Fairweather Inc Device Name: Xerox3545 For more information on Xerox products and solutions, please visit http://www.xerox.com Content-Description: ScanOOl.PDF Content- Type: applicationlpdf Content-Encoding: base64 1 of 1 1/24/2007 12:58 PM Rb: Kuparuk 22-11-12 . . Tom: Thanks for your questions and the catch on the Attachment II drawing. As I understand it, the "T" check will hold pressure from below, but it is possible to pump through it if the pressure beneath the check is exceeded. Conversely, it should be possible to bleed off any pressure above the check. At least that is the way it is supposed to work, but this is a very old well, and we will be prepared for surprises. In Step 4 on the procedure, BP wants to test the tubing to 1000 psi over whatever pressure is in it now (2460 psi, if the old gauge is correct). This should be below what it will take to pump into the perfs. The notation on the drawing referencing a bridge plug at 2830 ft should have been removed. I am sending over a corrected drawing. BP is now saying that they would like to cut the tubing at 300 ft rather than 2835 ft as originally proposed to minimize the amount of tubing that has to be pulled. It looks to me like it really doesn't matter where the tubing cut is made as far as the integrity of the P & A is concerned, so I have introduced an "as directed by the Wells Group" qualifier in the revised procedure that I will send over tomorrow. Hopefully the revised version will satisfactorily address the questions you have raised, including the need for a positive test on the tubing/casing annulus. Thanks for your help with this. Regards, Bob -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Tuesday, January 23, 2007 3:19 PM To: Bob Gardner Subject: Kuparuk 22-11-12 Bob, I am reviewing the plan for this well and have a couple of questions. 1. Does the "T" check in the nipple at 1991' provide the ability to hold pressure from above? 2. In step 3, it is planned to test the tubing to 1000 psi. Earlier it is stated the the pressure on the tubing is 2460 psi. If the answer to question 1 is yes, it would appear that you would need to pressure above 2460 psi to close the check. Would you please reconcile this information? 3. On the "after drawing" there is a notation of a bridge plug at 2830' with cement on top up to 2620'. regarding this. 4. Although several tubing tests specifically regarding the tubing I did not see anything in the plan are planned, I don't see anything x casing annulus other than to monitor it while pressure testing the tubing. The integrity of the casing should be positively demonstrated. Thanks in advance for your reply. Call or message with any questions. lof2 1/24/2007 7:36 AM . . RECEIVED E & P SERVICES, INC. JAN 1 9 2007 Alaska Oil & Gas Cons. Commission Am::horage January 18,2007 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 9950 I Attention: Tom Maunder, P.E., Petroleum Engineer Re: Application for Sundry Approvals, Form 10-403 B. P. Exploration (Alaska) Inc. (BPXA) Kuparuk 22-11-12, PTD 176-009 Dear Mr. Maunder: Please find attached the above referenced application and supporting documentation to plug and abandon Well No. Kuparuk 22-11-12. This work is necessary in order for the remediation of the 24-11-12 pad to be able to proceed during the first quarter of2007. If you have any questions after reviewing the application, please contact the undersigned at 907 258 3446, or Douglas Cismoski at BPXA (907 564 4303). Si~,~ ~~~~ R. C. Gardner Sr. Technical Advisor Fairweather E & P Services, Inc. Attachments cc. Douglas A Cismoski, P. E. , BPXA Chuck Stilwell, BPXA 2000 East 88th Avenue' Anchorage, Alaska 99507 . (907) 258-3446 . FAX (907) 279-5740 650 North Sam Houston Parkway East, Suite 505' Houston, Texas 77060' (281) 445-5711 . FAX (281) 445-3388 ~ _·W___·__..·_.~ ........_. . ~__.n._,_...,........~........~.......~·_....._··~~~.. _ ,.....-..,·,~".-"'''''..,"'-''"..W_....~....·u....~__~'_":':H:;:T:~;·-::::..::~·.;: :::::.~'.; ;,:"'.",.',~. ~ÆØ r¡: RECEIVED 'c"'("'''''''c,:""~".~,,,.l)"~'''::''i·::::;:''J'A:N'''l:;ò'-"9E':2~Ô'åì~""'~""":i Alaska Oil & Gas Cons. CommÎss on Anchorage ~ " D. r/<2:.o/;/ 1. Type of Request; STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 Operational shutdown 0 Plug Perforations 0 Perforate New Pool 0 4, Current Well Class: Development 0 Stratigraphic 0 Suspend 0 Repair well 0 Pull Tubing 0 Perforate 0 Waiver 0 Stimulate 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: Exploratory 0/ 176-000 / Service 0 6. API Number: 50-029-20192 / Other 0 Abandon 0 Aller casing 0 Change approved program 0 2. Operator Name: BP ExpJoration (Alaska) Inc. 3. Address: PO Box 196612 Anchorage, AK 99519.£612 7. If perforating, closest approach in pOOl(s) opened by this operation to nearest property line where ownership or landownership changes: NI A Spacing Exception Required? Yes 0 No 0 Ku aruk 22~11.12 I 9. Property Designation: 10. KB Elevation (ft): 11. Field/PooJ(s}: ADL 47451 ,Surf. Loc ADL 28263 BHL 64 ft J Prudhoe Sa I 12. PRESeNT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth lYD (ft): Effective Depth MD (ft); effective Depth TVO (ft); Plugs (measured): 10192 9192 10093 9093 10093-10192 l.engtll Size MD iVD Casing Structural Conductor Surface Il1termediate Production Burst Collapse i · ~ ! i · ~ ì · 1 ~ R ~ fi ~ ~ ~{ ~ · R ~ Ÿ ,j 5 (; M ~ &; ~ ~ !t ¡ f ¡ I , 8. Well Name and Number; Junk (measured): None 11' 735' 2723' 10,172' 30· 71' 71' 20" 735' 735' 1530 5:20 13 3/8" 2723' 2723' 5380 2610 7" 10,172 9174 8180 5120 Uner Perforation Depth MD (ft): See attached Packers and SSSV Type: Perforation Depth TVD (ft): See attached Types unknown Tubing Size: 41/2" Tubing Grade: Tubing MD (ft): 12.6#, grade unknown 9657 Packers and SSSV MD (ft): Prod.Packer@9579', x-nippJe@19991' 13, Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 15. Estimated Date for Commencing Ope¡atiOl1s: 17. Verbal Approval: Commission Representative: 18. I héfeby certify that the foregoing Is true and correct to the best of my knowledge. Contact Printed Name Douglas A Cismoski (907) 564-4303 TItle Wells Team Leader, Alaska Dritring and Wells Signature J:) .~ Phone t l{~e () 1- COMMISSION use ONt. Y Date: 14. Wel! Class after proposed work: Explorato¡y 0 Development Jan-01 is. Well Status after proposed work; 011 0 Gas 0 WAG 0 GINJ 0 o Service 0 Plugged 0 WINJ 0 Abandoned WDSPl o o ~ ! ~ ~ i I ¡ ¡ ¡ i ~ ~ ! ! I ¡ ! ! I ¡ I ¡ CondItions of approval: Notify Commission so that a representative may wilness Sundry Number: 7 Plug Integrity R BOP Test ~ Mechanical Integrity Test 0 Location Clearance 0 Other:~®~ J f:\..OG C-C \ \-.. .lç~~ O-.~ ~'j ~ \o.-~~~~~ I .ço\-\o~~\:" ~ It ~ \'eSSù\1è ~\:,~ ~ì.w ~.p P\~~ ~~ ~\,)\-<::::>~ _ 4S-0è)~",;>\ 'ßO't> ~~ ~O--"-" plo..,,~~, Subsequent Form Required: '-{ö \ APPROVED BY THe COMMISSION Date: ~ r-ð 1- Approved by: RBDMS 8Ft 2 ~ 2007 Submit in Duplicate . . ,,_~.-: ~,~,_~,...,~_ ,,:'L Based on a t can be safely p III have been deve · · -~-~~-.,. .,-"",~,~.....,---~,,,,, ( Perfs ~ HiO' - 9935' PBTD ~ 10093' BOT T, 29#, s.96, BTe ~111'11T emt Stage 1; 500 sx "G" ro ~ 10192' Kupal1kst 22-11-12 Fairweather E & P Services. INC. Rev. œ IN 10125J05 Drawing No! to Scala ... NœIey 1 012:512005 ---- -'-------~--= ( ( Attachment II 'nc. Proposed 1" M"IIIm! 20", W, H-40 BTC @135' Cmtd to suri'ace '1114000 1tt PGrm~ cmt Mflc Pack fO Coliiii' @151' Bar MR @2œ2' UIIIII'l'IlIlIþf@2020' Uner ~er @201!i' IiOWCO FO CoIIIII'@2251', $tæ;e 5: f'umplld 260 bbls AI'I::tIç Pack -- "0·- Cmt plug @ 9651' to TO Pelf¡ @ 9!132' . 9f.IoW (SClJIIII!IZ&d) Film @9862' . 9892', (Squel!lZ&d) Pelf¡ @9910' . 9935', (Squee:t:ed) 1", 29ft S-&5, src @ 1Q172' Cmt Stage 1: 500 $)( "G" !roT landing coIlar@10115' BOT Catcher sub @ 11)128' TO @ 10192' !(¡,pamk$!.22-11-12 F~er E & P Serv!cæ, INC. Ri!I\I. as Jill 10125105 Dra\Aoing Not to Scaié ...-......,,10120f.Z00!í " . .... .. ~~ --"-----"">" '-'--~-'~',,,,.'--:"':'.~'~;"-' Attachment III BP Exploration (Alaska) Inc. ~paruk 22-11-12 PTD 176-009 API No. 50-029-20192 Well P&A Operations Program Su a avel pad that is no 10 well for asica1ly standin own. While there is ker in this well, P & A operatio g that, due simply to age, thes operations program is based d under winter conditions. P&A Proeram 1. Construct ice road over the therm.okarsted section of the old gravel road route between "W" pad and the well location. 5. · 6. f. g. h. 9. <' I . . , _." _.'~_'';'''-''_''''_~''~__ .,~;~_. ~:_ __~'__"__"'_',_~__ 'ra~~-~~_". 1 O. Prep to cut and pull tubing. Rig up 60-ton crane ipe bin. Pressure test lubricator, RIH with 3.625" jet cutter. Make mid Joint tubing cut between 300 ft and 2835 ft as directed by Wells Group. Record tùbing and annular pressure before and after cut. 11. Rig down slickline unit. Corrfinn that tubing is free by unseating tubing hanger. Pull tubing rane and lay down. Remove tree. 12. Rig up slic to bri down cementers. pen end 2" P P batch mixer and p ent T casing to surface. Leave PVC pipe in place. Rig do 13. While WOC, excavate and remove well cellar/ Segregate any contaminated gravel as directed by Oasis representative. Extend excavation to 6 ft below original tundra surface. 14. Rig up Wachs Saw. Rig up loader or crane to support wellhead. Cut all casing strings 4 ft below original tundra surface. Remove wellhead and cut-off casing sections. ". \ _ ' \. \ (' (\ f\O-+~'L þ..,OCòu:. ~\"o~ çct~\,\ -\-'-- ìO~' \'-\".C:"".ö>,> c..ù"\ ð'\-~ IS.F 'ds in annular sp 'thcement M~ re e marker V;) '; 10-407 report with AOGCC referencin NOTES: (1) Advise AOGCC 24 hours in advance of (Telephone: 659-2714, P (2) Hold safety meetings before starting anyon-site operations, and before all subsequent critical operations. Standard Alaska Produc lion Company 900 Eos! Benson Boule,,o,d PO Bo~ 19661~ Ancho~oge Alosl~o 1907) 564..5 I ! I INDEXED STANDARD ALASKA PRODUCIlON DALLAS ' ARCO CHEVRON EXXON TEXACO MOBIL PHILLIPS STATE OF ALASKA Date: 09/21/87 TO: TI: 78183 REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following material ls being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning It to this office: ~ B-27 Flowing/Gradient 09/07/87 Camco '~ B-27 " " 09/13/87 " ",B-28 Static Gradient 09/06/87 Camco -~ B-29 Flowing Gradient 09/10/87 Camco "' J-2i Static Gradient ' 09/12/87 Camco '" J-23 " " 09/10/87 Camco -- K-1 " " 08/21/87 Camco '" Y-20 " " 09/03/87 Camco '"'Y.20 " " '09/06/87 Camco "Y-21 " " 09/08/87 Camco ~ Kuparuk State 22-11-12 Static Gradient 08/26/87 Camco Received Date RECEIVED ~_tj ~ T, ~:~:t Oil &.G~ Cons. i;0mmlssi0[t Anch0mge Victoria Aldridge INFORMATION CONTROL Well Records LR2-1 Standard Alaska Production C~mpar~ 900 East Benson Bo P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-511 STANDARD ALASKA PRODUCTION/ December 2, 1986 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Gentlemen: Well Kuparuk State (22-11-12) PBU Enclosed in duplicate is Form 10-407, Revised Well Completion Report, for the above-named well. The revision changes the well status from a suspended well to a service well classified as an observation well. Very truly yours, STANDARD ALASKA PRODUCTION COMPANY RSA/MkW/pm/1402D Enclosure cc: Well File #17 R. S. Allan Division Drilling Engineer A unit of the original Standard C~I Company Founded in Cleveland. Ohio in 1870. '-'~-.Original Well Completion Report 10-27-8i. Revised 11-19-86. Classify Service Well as an ' ~'~-~-, STATE OF ALASKA * -~'~ Observation Well. AL~;--- _L AND GAS CONSERVATION ~' .MISSION WE'lL COMPLEYION OR RECOMPLETIONREPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE ¢~ Observation .... 2. Name of Operator 7. Permit Number Standard Alaska Production Company 7~-q -- -- 3. Address 8. APt Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20192 4. Location of well at surface 9. Unit or Lease Name 1742' NSL, 744' EWL, Sec. 23, TllN, R12E, gM Prudhoe Bay Unit At 'Top Producing Interval 10. Well Number 3089' N:~L, 2286' WEL, Sec. 22, TllN, R12E, UM Kuparuk St. 22-11-12 At 'Total Depth 1 1. Field and Pool 3134' NSL, 2387' WEL, Sec. 22, TllN, R12E, UM Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Oil Pool KBE = 64' AMSL 47451 (surface) 28263 (bottomhol:e) 12. Date Spudded 13. Date I.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore I 16. No. of Completions 3/8/76 5/9/76 7/26/81I i .[~'/A feet MSLI One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 10192'MD 9192'TVD 10093'MD 9112'TV£ YES [] NO [] 1991 feet MDI 1950' -- 22. Type Electric or Other Logs Run CBL/VDL/CCL/GR, Spectralog, TDT, Gradio 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" 156# LP Surface 71' 36" 125 sks Permafro.~t 20" 94~ H-40 Surface 735' 26" 4000 sks Permafrost 13-3/8" 72~ N-80 Surface 2723' 17-1/2" 5000 sks Permafrost 7" 29~ Soo-95 Surface 10172' 8-1/2" 500 sks Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) MD TVD 4-1/2" 9657 ' 9579' Top: 9832' 8895' Prudhoe Oil Pool: Bottom: 9935' 8980' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 9832-9845'BKB 0.5"@4spf(Ref. BHCS/GR,5/10/76) 9860'-9935' 200 sks Class G w/l% frictiol 9862-9892 ' BKB " 8spf ( " ) reducer 9910-9935' BKB " 8spf ( " ) 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 7/16/81I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE IGAS-OIL RATIO 7/16-26/81 77 TEST PERIOD ~ 2650 1244 25 1"I 566 .SCF/STB Flow Tubing Casing Pressure CALCULATED OIL-DEL GAS-MCF WATER-DEL OIL GRAVITY-APl (corr) Press. 174 zero 24-HOUR RATE ~ 900 414 9 22.3°API @ 60°F 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ~;.:~-2- ~*--'~ ~ .. ~., .... ,; ,- Form 10-407 Submit in duplicate Rev. '7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Upper Cretaceous LoWer Cretaceous- Top of Kuparuk Base of Kuparuk Total Depth 31. LIST OF ATTACHMENTS 32. · GEOLOGIC MARKERs MEAS. DEPTH BKB Lost in Pe: TRUE VERT. DEPTH BKB ,mafrost 30, , .. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 5787' 6236' 6397' 6550' 5787' 6236' 6397' 6550' I hereby certify that the foregoing is true and correct to the best of my knowledge Division Drilling Signed - . Engineer INSTRUCTIONS General: This form is designed for submitting a complete and correct wel completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item :28: If no cores taken, indicate "none". Fnrm I N-ZIN? Telecopy No. (907) 276-7542 November 26, 1986 Mr. R. S. Allan Division Drilling Eng{neer Standard Alaska Production Company P. O, Box 196612 Anchorage~ AK 99519-6612 Re: Extension of Suspended Status Getty State Well No. 1 Kuparuk State 22-11-12 Niakuk Well No. 6 Dear Mr. Allan: On October 22, 1986 we received "Application. for Sundry Approvals", Form 10-403, for a number of wells, including those referenced above, requesting one-year extensions of suspended status. Ail of the 10-403's except for the subject wells, were approved and returned, The ~0-403 s for the subject wells were not approved, and are being returned with this letter. The reasons these were not approved are as follow: Getty State Well No. 1 -- The completion report which we received on June 3, 1980 shows the status of the well as "observation"; therefore, yearly extensions of suspended status are not required. ~ Kuparuk State 22-11-12 -- This well is an observation well, and, again, yearly extensions of suspended status are not required, The completion report which we received on December 15, 1981 shows the status as "suspended- observation". According to current regulations this-well should be classified as "service-observation". Please submit a revised completion report showing this change.- Mr. R. S. Allan November 26, 1986 Page 2 · Niakuk Well No. 6 -- The completion report which we received on May 8, 1986 ¢lassifed this well as suspended. The well has tubing and packer installed, and has been perforated and production tested. Since the well has been completed and does not meet current requirements to be classified as suspended, we changed the well status to "oil well". Consequently, yearly extensions of suspended status are not, required. If you have any questions, please call Harold J. Hedlund at 279-1433. Sincerely, Lonnie C. Sm' h Commissioner Attachments Jo/A.HJH. 48 . MEMUH^NIJUM u] ~- ,'- ', ALASKA Oil- N GAS CONSERVATION COMMIS~''''~ C. ton -, DATE: September 8, 1986 .. ,.TO: Chain ' · - _ vItE ~o.: D.BDF.67- THRU: Lonnie C. Smith.lC'.5 C ommis s ioner 'm~OM: Bobby D. Fost'er~c~,' - · - Petroleum Insp ~r TELEPHONE NO.:' '"- SU~ECT: Inspect Suspended -' Well Locations SAPC - Listed Below Prudhoe Bay Field Tuesday, August 26, 1986: 'I inspected the suspended well locations listed below and found them to be acceptable for suspended well status: - Term well "C" M.P.C. Tract well ~1-11-33-11-12 M.P.C. Tract well ~21-3-10-12 Kuparuk ~22-11-12 Attached to this report are pictures of the locations and well heads. .- Attachments ' · 2-001 A(Rev Suspended 20 Well and Location AAC 25, ARTICLE 2 Report FI LE INFORMATION: Addre s s Date Suspended ._ ~"-' ~'" 2~ Surface Location of Well Ft. F L, Sec. , T_ __, R Ft. M. F L Unit or Field & Condition of Pad Con~[i tion of Pi ts ~>,~/~_~ Wel ]. head Wel 1 sign - Ail outlets plugged Attached to well head Attached to well guard Attached to Ye s Information correct No No No No Cell. ar - Opened Yes No Rat Hole Fil led Yes No Cove red Ye s No WaterWell - Plugged off Capped Open Explanation Open Fil led Covered Ye s No Ye s No Ye s No Photographs taken to verify above conditions~ No Expla naton Work to be done to be acceptable This well and location is (ac.c~ptable) (unacceptable) to be suspended for the period of ~/,~inspected. by~ ,~~/~'-/ _~.~'~." ~~~~ classified as Revised 8/24/82 INDEXED TO: DALES ~co STANDARD CHE~rRON AL ASKA PRODUCTION EXXON Date: 06/25/86 TEXACO TI: 77147 MOBIL PHILLIPS STATE OF ALASKA Page 1 of 2!! GEOSCIENCES REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following material is being subml~fed herewith. Please acknowledge receipt by signing a copy of this let-far and returning i? to ?his office: A-26 ~ BHP Survey A-29 ~" " A-31 ~.BH Pres. Survey A-33 '-t~HPD &"~BU A-33 ~Static Gradient A-34A "~PBU A-34A ~'BHPD F-17 ~static Gradient F-24 tatic Gradient J-3 ~'~tatic Gradient K-8 .~-BHPD '~--P BU M-10 x~S tat ic Gradient M-16 ~ " " M-19 ~" " M-21 --" " M-24 ~' °" N-7 "~survey N-15 ~'~-" Gradient N-18 x.~,, ,, N-19 ~-" " R-13 "~" " R-16 ~, R-19 " 05/28/86 Otis 05/29/86 Otis 05/11/86 Dres 05/09-11/86 Dres 06/03/86 GO 06/11/86 Camco 05/19-20/86 Camco 05/20/86 Camco 06/04/86 Camco 06/06/86 Camco 06/13/86 Camco 04/26/86 Otis 04/19/86 Otis 06/06/86 Camco 06/02/86 Camco 06/03/86 Camco 06/08/86 C-a~-~o 06/08/86 Camco 05/24/86 GO 05/31/86 Camco 06/05/86 Camco 06/05/86 Camco 06/10/86 Camco 06/11/86 Camco 06/07/86 Camco 05/21/86 GO Static Gradient 1! fl INFORMAT ION CONTROL Well Records LR2-1 Date- 06/25/86 T#' 77147 Page 2 of 2!! R~BHPD & Flowing Gradient 05/13/86 Camco S-16 ~ta~ic Gradient 05/27/86 Camco U-2 06/01/86 Camco U-10 ~BHPD ~Flowing Gradient 06/01/86 Camco U-12 '"'Static Gradient 05/27-28/86 Camco ---~22-11-12 Static Gradient 03/16/86 Camco ~; . · ,,. ' i ka 0~, & Gas Con Oommss Anchorage Victoria Aldridge LR2-1 Well Records LR2-1 MEMORANOUM State of Alaska ALAS~ OIL AND GAS CONSERVATION COMMISsIoN TO: C.V. Chatterton Chairman THRU: Lonnie C. Smith Commissioner FROM~ Bobby D. Fosterf?~ Petroleum Inspector DATE: October 1, 1985 FILE NO: D. BDF. 92 TELEPHONE NO: SUBJECT: Location Inspection Sohio P.B.U. Kuparuk State 22-11-12 Pemit No. 76-9 Prudhoe ~ Oil Pool ~gust 30, 1985: I met with Dick Maskell, Sohio Represen- ~~--in-~pee~~e following suspended location: Kuparuk State 22-11-12 Permit #76-9 - P.B.U. Attached to this report are pictures and a suspended well report. Attachment 02-00IA(Rev. 10t79) Suspended Well and Location 20 AAC 25, ARTICLE 2 Report INFORMATION: -- .... /9 ~ t/~ / . /.~ FILE ~-~a~ _'-._ ~ .~._~~ ~/~~, ~/~~ Date Suspended Address ~D~-~~ (~ ~iZ-~' 'W~~~~ .~~~ .... ~'_"'_'_ -- Surface Logation of Well Sec.~, T~ ~' , R~'-~/-~M. -'Un~=-or Lease Name f~---~ ]'~ ]:- -- Condition of Pad. Condition of Pi ts . _.~_,~~ Well head - Ail outlets plugged Wel 1 sign - Attached to well Attached to well Attached to head guard No Ye s No Information correct ~ No Cellar - Opened ~ No Rat Hole Open Yes ~ Fil led ~-es No Fil led Yes No Covered Yes No Covered Yes No WaterWell - Plugged off . Capped Open Explanation _-~_~ _ ~_ .~_ -_-_-_,. ~: -~_ _ ,, -~- _. _- - _ _- _ . --_-., _ ........... Photographs taken to verify above conditions No Work to be done to be acceptable _ . This well and location is~cceptabl~ (unacceptable) to be suspended for the period of Inspected 'bye, _~...._. . classified as 19~. Revised 8~24/82 SOHIO ALASKA PETROLEUM COMPANY 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 P.O. BOX 6612 ANCHORAGE, ALASKA 99502-0612 July 22, 1985 Mr. C.V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, /U< 99501 RE: 1985 LOCATION INSPECTION Dear Mr. Chatterton: In compliance with State Regulation 20 AAC 25.170, attached are Forms 10-403, Sundry Notices and Reports on Wells, for the following wells. These notices request that the wells remain in suspended status. BP 41 -33-1 2-1 3 BP 22-33-11-13 Term Well B (22-20-11-13) Term Well C (34-03-11-12) Chevron Tract Well (23-18-11-12) MPC Tract Well (21-03-10-12) PBU MP 43- 31-11-13 MPC 11-33-11-1 2 Getty State #1 (02-10-13) MP Tract Well (32-30-11-13) PBU MP (22-31-11-13) No. 2 West Sak 25645 #9 West Sak 25548 #11 West Sak 25655 #14 West Sak #16 West Sak #17 Kuparuk State 22-11-12 Sag Delta #1 (33-12-16) Sag Delta #2A (lO-Il-16) Sag Delta #3 (35-12-16) Sag Delta 34633 #4 Sag Delta #5 (36-12-15) Sag Delta #7 Sag Delta #8 Sag Delta #9 Sag Delta #10 Niakuk #lA (26-12-15) Niakuk #2A (23-12-15) Alaska Island #1 Niakuk #4 Niakuk #5 Mr. C.V. Chatterton July 22, 1985 'Page 2 Sag Delta #11 is now ready for final inspection of the abandoned wel 1. Please advise the undersigned which day during the week of August 19-23 is acceptable for your field inspector to accompany our representative for this annual location inspection trip. Very truly yours, RSA/CRM/sh 72285:0530N Attachments cc' Well File #17 R.S. Allan Acting SAPC Drilling Engineer STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C,JMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL r-I COMPLETED WELL [] OTHER 2. Name of Operator Sohio Alaska Petrole~n ~y 3. Address Po,?h 6-612, An_~_h~rage, Alaska 99502 4. Location of Well At surface: 1742' NSL, 744' EWL, Sec. 23, TllN, R12E, UPM 5. Elevation in feet (indicate KB, DF, etc.) 1eRR. = 64' ~vtqT. 6. Lease Designation and Serial No. ~ 28263 7. Permit No. 76-9 8. APl Number 50- 029-20192 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number Kuparuk State 22-11-12 11. Field and Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: Request extension under (Submit in Triplicate) 20 ~ 25.170 (b) 1,2,3 Perforate r"l Alter Casing [] Perforations Stimulate I-'] Abandon [-]~ Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other ~] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other [] [] [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Reason for extension: This well is currently being used as a Prudhoe Bay Unit observation well. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~----~ ~-~' ~ Title District Drilling Engineer The space below for Commission use R. H. Reiley Date Conditions of Approval, if any: Approved by COMMISSIONER Approved Copy Return~;I _/51/ By Order of the Commission Date Form 10~t03 Rev. 7-1 Submit "Intentions" in Tripl,cate and "Subsequent Reports" in Dupl,cate SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON TEXACO TO: sFo/uNIT/STATE: (-Mar a t hon) MOB IL PHILLIPS STATE BPAE (Transmittal Only) 3~i I 1 "C" ANCIt()t~A(][. ALASKA ~'£L[!P*,IONE (9()']~ 265-0000 MAIL. POUCH 6 612 ANCHORAGE. ALASKA 99502 Date: 4/26/85 T#: 76152 REFERENCE: he following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- B-2 PBU 4/11/85 GO BHPD 4/12/85 GO F-4 PBU 4/17/85 GO BHPD 4/18/85 GO Kuparuk State (22-11-12) 3/18/85 GO (Static Gradient) RECEIVED DATE M EMOR,,N DU M of Alaska ALASKA OIL AND GAS COI~SERVATIOI~ COMMISSION /'---~: :': TO: C. V. / C¢~:~erton THRU: Lonnie C. Smith Co~issioner DATE: September 19, 1984 F,LENO: D.21.36 TELEPHONE NO: FROM: HaroId R. Hawkins Petroleum Inspector SUBJECT: Clean-up Inspection For Extension of Suspended Status, Sohio Alaska Kuparuk St. 22-11-12, Sec. 23, TllN,R!2E,UPM Permit No. 76-9. Monday, August 6, 1984: I left Long Island, subject of another r~'t~':~-t8' 'sbh:i0~s Kuparuk State 22-11-12 location. i inspected the location, well sign and mud pit. The luraber that was on location the last inspection made by Ed Sipple was gone. All the required regulations for clean-up inspection for extension of suspended status is performed. I filled out an AOGCC report which is attached. I also took pictures for verification to be attached to this report. In summary, I inspected Sohio's Kuparuk State 22-11-12 location and found that all the requirements for extension of suspended status was met. I reco~end the extension of suspended status is approved. Attachment/pictures in file 02-00IA(Rev. 10/79) Suspended Well and Location Report 20 AAC 25, ARTICLE 2 FILE INFORMATION: , ~ ·, , ~ Operator 3~ /~'/ ~ /~~/t'/~_ Addre s s Surface Location of Well Ft. F L, Ft. F Sec.~_, T // _~_, R~_~ .-_~_, ~__M. Date Suspended Pe rmi t No. ? _~' ~: ~ L AP1 No. Unit or Lease Name Well No. Field & Pool Condition of Pi ts O ? Well head - Ail outlets plugged Wel 1 sign - Attached to well head Attached to well guard · Attached to Information correct No Ye s No No Cellar - Ye~' No Rat Hole Open Yes No Ye s No ~ ~ No Cove red Ye s No Cove red No WaterWell - Plugged off capped Open Explanation Photographs taken to verify above conditions ~ No E x p 1 a n a t o n ~ 7~_?'/~z~'//~_-Z9 Work to be done to be acceptable This well and location is (acceptable)' (unacceptable) suspended for the period of 19 thru Inspected by:_ . _ _ Date:_ to be classified as 19 . Revised 8/24/82 SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 July 10, 19 84 Mr. C. V. Chatterton Alaska Oil & Gas Conservation Ccmm~ssion 3001 Porcupine Drive Anchorage, Alaska 99501 Re: 19 84 LOCATION INSPFLTION Dear Mr. Chatterton: In oompliance with State Regulation 20 AAC 25.170, attached are Forms 10-403, Sundry Notices and Reports on Wells, for the following wells. These notices request that the wells remain in suspended status. BP 41-33-12-13 BP 22-33-11-13 Term Well B (22-20-11-13) Term Well C (34-03-11-12) Chevron Tract Well (23-18-11-12) MPC Tract Well (21-03-10-12) PBU MP 43-31-11-13 MPC 11-33-11-12 Getty State #1 (02-10-13) MP Tract Well (32-30-11-13) PBU MP 22-31-11-13) No. 2 West Sak 25645 #9 West Sak 25548 #11 West Sak 25655 #14 West Sak #16 West Sak #17 Kuparuk State 22-11-12 Sag Delta #1 (33-12-16) Sag Delta #2A (10-11-16) Sag Delta #3 (35-12-16) Sag Delta 34633 #4 Sag Delta #5 ·(36-12-15) sag Delta #7 Sag Delta #8 Sag Delta #9 Sag Delta #10 Niakuk #lA (26-12-15) Niakuk #2A (23-12-15) Alaska Island #1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL I"1 COMPLETED WELL I-1 2. Name of Operator 7. Permit No. Soh.i~ ~l~sY~ Petz~letza ~¥ 76-9 3. Addres~ 8. APl Number POUC_~ 6-612, N~c.t~rage, /L[asY~ 99502 so-029-20192 4. Location of Well OTHER At surface: 1742' NSL, 744' f~L, Sec. 23, TllN, R12E, UPM 5. Elevation in feet (indicate KB, DF. etc.) KBE-- 64' AMSL 6. Lease Designation and Serial No. 9. Unit or Lease Name 10. Well Number K~ slam 22-11-12 11. Field and Pool ~aay t~dtx~e 0~1 ~ool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: ~ ~i(:~t ~ (Submit in Triplicate) 20 2U~C 25.170(b) 1,2,3 Perforate r'l Alter Casing I'1 Perforationl Stimulate [::] Abandon [:::]' Stimulation Repair Well I--i Change Plane I--I Rel:mirs Mede Pull Tubing [:::] Other ~] Pulling Tubing (Note: Re~ort multiole completion~ on Form 10-407 with a submitted Form 10-407 for each comgletion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) I-] Altering Casing I-1 Abandonment I--I Othm' 0 0 0 13. Describe Proposed or Completed Operation~ (Clearly state all pertinent details and give pertinent date~, including estimated date of starting any proposed work, for Abandonmeftt see 20 AAC 25.105-170). Reason for extension: This well is currently being used as a Prudhoe Bay Unit observation well. Thl~l~OW for Cmmiuio. u. R' H. ~~ ~ ce~,~o,, ~, A~,ove,. ~, .-v: S~pen~d sta~s :s ext~ded ~til ~pt~er, 1985. ~pprove~ Copy A~tO~ by, COMMISSIONER the C~miuion SOHIO ALASKA PETROLEUM COMPANY SF0 ARCO CHEVRON EXXON GETTY TO: SFO/UNIT/STATE: (-Marathon) MOBIL PHILLIPS STATE OF AK BPAE (Transmittal Only) CENTRAL FILES (CCf!' s-Transmittal Only) 3111 °'C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502 Date: 4-16-84 CC~/: 75219 REFERENCE: ~_S~ CASED HOLE FINAL LOGS The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- Kuparuk St. (22-11-12) KUpamouk! :St, (.22-11-12) EPL 2-6-84 #1 9654-10045 Sch TDT-M 2-7-84 #2 9650-10055 Sch (4~82) RECEIVED DATE ~'~ ~ '~ ~:? ~:~:~":~~evelopment Geology Well Records ., SOHIO ALASKA PETROLEUM COMPANY lO SFO ARCO EXXON PHILLIPS STATE OF AK CENTRAL FILES(CC#'s-Transmittal Only 31 1 1 "C" STREET ANCHORAGE. ALASKA TELEPHONE (907) 265-0000 MAIL POUCH 6-612 ANCHORAGE. ALASKA 99502 Date: 3-23-84 CC#: 76154 REFERENCE: ThefSOHI__O MAGNETIC LIS TAPES & LISTINGS ollowing material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- SFO/UNIT/STATE: *R-9 2-12-84 #2 C.H. LIS w/ Lis ting Sch t/69008 *Kuparuk St. 2-7-84 #2 C.H. TDT-LIS w/ Listing Sch #69004 C.Ho T.a, pe Pos. # 02903 (4/s2) *SFO & EXXON: An Asterisk (*) next to a listing abouve means you should have received the Tape(s) and Listing(s) directly from the respective service company. Please confirm this. RECEIVED .............. Carolyn Bishop Development Geology OAT~. ............................ 19 Well Records November 8, 1983 Mr. R. H. Re iley Distric Drilling Engineer Sohio Alaska Petrole~ Company Pouch 6-612 Anchorage, Alaska 99502 Re... Site Clean-up Corrections for: Kuparuk State 22-11-12 Sag Delta 7, 9, and 10 West Sak ~o. 14 Dear ~r. Reiley~ Reference is made to your letter of November 2, 1983, regardin~I correction of clean-up deficiencies of these wells. PhotograPhic evidence sub,~itted~ is accepted. · as evidence tl~at clean-up is now satisfactory at suspended location Kuparuk State 22-11-12 and Sag Delta 7, 9, and The approved time extension ' request (10-403) allowin~ you to retain oil booms in place at West Sak ~o. 14 is enclosed. Sincerely, . . ~ Lonnie C. Smith Co~nmissioner Enclosure J~/LCS: !c: t03, B SOHIO ALASKA PETROLEUM COMPANY Mr. Lonnie C. Smith, Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 3111 "C" STREET ANCHORAGE. ALASK~ '[E LEPHONE (907)276-5~1 f_~_~__ MA,L: POUCH 6-612[ -~-~i'-~-~'----- ANCHORAGE, ALASKA E~'~-~'~' ~E~ i , : ~;r,.xT ~c-' ~ - . ~ FILF: Dear Mr. Smith: Re: 1983 LOCATION CLEANUP INSPECTIONS Kuparuk State 22-11-12 Sag Delta Wells, 7, 9 and 10 West Sak ~14 Reference is made to your letter dated September 12, 1983 regarding the subject well sites. Enclosed photo #1 shows the site of ~~~te 22-11-12. Tent, pallets and timbers belonging to third party were removed and neatly stacked at one of their caribou observation platforms as shown in Photo #2. Photos #3 and #4 were taken at Endeavor Island after cleanup (site of S~__ Delta ·Wells 7, 9 and 10). The remaining timbers are being used to cover cellars for protection of personnel. You will recall our telecon regarding West Sak #14 well site. We desire to keep the oil booms remaining in place at this time for containment purposes in the continuing cleanup of this site. Very truly yours, R. H. Reiley District Drilling Engineer RHR/MCM/pw Enclosures cc: Well Files #17 - ~.~. %.'.;,. '"% :.,.. o. ' bT~ oD 15 'W H F___ e& Photo #1 Photo # 2 September 12,. 1983 Mr. R. F.. Bei~ey District Drilling Engineer Sohio Alaska_ Petroleum Company Pouch 6-6!2 Anchorage, Alaska 99502 Eear ~r. Reiley: :.-.i-: ....regarding extension of time for 28 suspended wells· Submitted on ,.-.v.,;>- ........ July '21, 1983. These ~,ull sites were inspected by our re~resent- ,~-..~-~::':~/:~'.ative-on August 8 and 9, 1983.-. The following four sites .need '~:.~..~..~ . further cleanup Fuparuk_ State 22-11-12, remove ~allets and timber Sag Delta 7, remove electric cable. Sag Delta 9, remove loose L~ards Sag Delta 10, remove timbers . '~'"~ ·" It~ is requested that this cleanup be acc~f~.lished and verified by ..... · .... photographs to this office-as soon as possible. Enclosed ~re approved Sundry Notices and Re~orts on Wells (10-403's), Sincerely, · ~ . Lonnie C'. Smith Commissioner A t t achme nts FROM: MEMORANDUM State of Alaska ALASKA CIL/~-~.D -.CAS COI~SEI?VATIC~ CO~.~b~ISSICD /i i/ August 25, 1983 chai~an~~' '"~' ~ /..'.)~," FILE NO: 10 8A: t" 4 T}~Rf~: ~nnie C. Smith Comr3,is s ioner " TELEPHONE NO: ~dgar W. Sip~le, J~~ su~c~: ~troleum Inspecto~ Inspecton on Sohio'r.~,' Suspended I,ocations I. isted Delow. ~es¢,a~3,.. AUg.U_st 9, 1983: I traveled this date with [..like DiDger, Sohio's reF-resentatiave, to look at the susl;ended locations listed., below: t';iakuk lA (26-12-15) f~iakuk 2A (23-12-15) Te~ ¥'~ell D Te~ ~,~el 1 C ¥.uFaruk 22-11-12 State fl (2-10-13) ~ttached to this report are ~-ictures of the well head, drillin.~ pads, reserve pits, and a coFy of the AOCCC surface sus,~>ension locaticn report. It is my recolr, mendation to the Con:mission that the a]:.ovc lc, ca- tions k,e acc-3~ted in regards to ].ocation cleanuF, ~,cl] si~3n placement, and Fit conditions, witk the e>:ce~_.,ticn of }~u~a~'~k 22-1~.-12, after the pallets 'and 2 x 4's are ren;oved fror; this location, appr-ove this location Atta ch~.nt s Suspended Well and Location Report 20 LAC 25, ARTICLE 2 FILE INFORMATION: Operator 7~t I __(~tl ~_~ Date Suspended Address '~-~ ~~ -~%3U~f. ~g;~. ~0 ~' ~ Surface Location' ~-f-~el~~ - Permit No. 7~L~~ ..~.7~ Ft. F C L, ~7~q Ft. F ~ L A~I No. ~0 ~9- Sec.~ , T_// ~' , a/~ ~ ,~ ~ M. Unit or Lease Name ~b,~.T~A~]~F$:~A% Field & Pool _~~9~' ~y Condition of Pad ~,: Condition of Pits Well head - Ail outlets plugged Well sign - Attached to well head Attached to well guard Attached to Ye s No ye s, No : Ye s No Information correct Yes No Cellar - Opened (~ No Fil led Yes ,~ Cove r ed Ye s ~D WaterWell - Plugged off Rat Hole Open Fil le d, Covered capped Open Explanation Ye s No ye S No Ye s No Photographs taken to verify above conditions ~L~o Explanaton Work to be done to be acceptable ..... f_~..~ .... This well and location is (~~4~t~) (unacceptable) to be classified as suspended for the period of,~ 19 thru 19 . Inspected by: Da te: Revised 8/24/82 SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREE'r ANCHORAGE, ALASKA TELEPHONE (907) 276-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 July 21, 1983 Mr. C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 1983 'LOCATION INSPECTION Dear Mr. Chatterton: In compliance with State Regulation 20 AAC 25.170, attached are Forms 10-403, Sundry Notices and Reports on Wells, for the following wells. These notices request that the wells remain in suspended status. BP 41-33-12-.13 BP 22-33-11-13 Term Well B (22-20-11-13) Term Well C (34-03-11-12) Chevron Tract Well (23-18-11-12) MPC Tract Well (21-03-10-12) PBU MP 43-31-11-13 _MPC 11-33-11-12 Getty State #1 (02-10-13) MP Tract Well (32-30-11-13) PBU ~? 22-31-11-13, No. 2 West Sak 25645 #9 West Sak 25548 #11 West Sak 25655 #14 West Sak #16 West Sak #17 Kuparuk State 22-11-12 Sag Delta #1 (33-12-16) Sag Delta #2A (10-11-16) Sag Delta #3 (35-12-16) Sag Delta 34633 ~4 Sag Delta #5 (36-12-15) Sag Delta #7 Sag Delta #8 Sag Delta #9 Sag Delta #10 Niakuk #iA (26-12-15). Niakuk #2A (23-12-15) Alaska Island #1 Mr. C. V. Chatterton July 21, 1983 Page Two Water Injection Well GC - lB (13-11-13) is also now ready for final inspection of the abandoned well site. Please advise the undersigned which day during the week of August 8th is acceptable for your field inspector to accompany our representative for this annual location inspection trip to the above-n~ well sites. Very truly yours, R. H. Reiley District Drilling Engineer encs cc: Well Files #17 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION Cu,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. Sohio Alaska Petrole~a ~y 76-9 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-20192 4. Location of Well At surface: 1742' NSL, 744' EWL, Sec. 23, TI]N, R12E, UPM 6, Lease Designation and Serial No. ADL 28263 9. Unit or Lease Name Prudhoe Bay Unit OTHER 10. Well Number Kuparuk State 22-11-12 5. Elevation in feet (indicate KB, DF, etc.) KBE = 64' AMSL 11. Field and Pool Prudhoe Bay Prudlx~ oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data [] [] [] NOTICE OF INTENTION TO: Request extension under (Submit in Triplicate) 20 .ZLA. C 25.170 (b) 1,2,3 Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other ~] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Reason for extension: This well was reccm~leted in 1980 as an observation well. Date 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed [~,.~.~) ~_~.__'~, I~ /F~ District Drilling ~g~r The space below for Commission use R. H. ~%ley Submit "Intentions" in Triplicate Form 10403 Conditions of Approval, if any:This location was inspected by our representative on August 9, 1983 and clean up was found satisfactory_/except need to remove pallet and lumber, for a suspended location. A subsequent inspection will be necessary by August 1984. ORIGINAL SiI~N[D By Order of 2- ~~- 0¢; ~---'~ Approved by .~.~ [~N~]E _~. ~!.T.~. COMMISSIONER the Commission Date ._ SOHIO ALASKA PETROLEUM COLIPANY S¥0 ARCO '., CHEVRON EXXON 311 i '°C" SIf~EET ANCt~OHAG[. ALASKA TELEPHONE 1907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 GETTY '~o: S FO/UNIT/STATE: (-Marathon) MOBIL PHILLIPS BPAE (TransmSttal Only.), CENTRAL FILES (CC#'s - Transmittal Only) Date: 1-26-83 Trans.#: 3068 CC#: 56068 RE~: ' . ~IO FI.______~N% DAT____A_- PRESSURE SURVEY DATA copy of this letter and returning it to this office:-- F-18 ., BHPD (CORRECTED COPY) Getty State ell'- Pressure Survey MPC 22-11-12~ Pressure Survey G-15 ~- Pressure Survey G-17'-. Pressure Survey & BHPD F-14 ~ " " X-3 ~ " " C-2 ' " " B-2 "' " ,. C-8 ~" " " G-14 " J-2 /=' " " 12/19/82 Sch 1/4/83 Otis 1/2/83 Otis 12/31/82 Otis 11/28/82 GO 12/9/82 Otis 12/1/82 Camco 11/22/82 GO 11/16/82 GO 11/19/82 Sch 1/18/83 GO 1/16/83 GO ~/82) RECEIVED DATE Karem Venn Development Geology Well Records MEMO ,NDUM S. te of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION TO:c. ~~a~terton DATE: November 9, 1982 Cha~ RtE NO: 108/A Thru: Lonnie C. Smith~ CommissionerI TELEPHONE NO: FROM' Doug Amos ~.~-, Petroleum Inspector SUBJECT: Inspection of Sohio' s Suspended Locations Listed Below Friday, August 27, 1982 - I traveled this date to Prudhoe Bay where I met Jerry Segar, Sohio representative, and conducted the second clean-up inspection on the locations listed below. Attached to this report are pictures of well heads, reserve pits, drilling pads and a copy of the Form 10-403. I recommend to the Commission that the following locations be accepted in regard to location clean-up, well sign placement, and pit condition. PBU MP 22-31-11-13 No. 2 Term Well B (22-20-11-13) Term Well C (34-03-11-12) MPC Tract Well 21-03-10-12 MPC 11-33-11-12 Getty State No. 1 (2-10-13) PBU MP 43-31-11-13 West Sak 25645 #9 (3-11-9) West Sak 25548 #11 (36-12-8) West Sak 25655 #14 West Sak #16 (31-36-13-08) West Sak #17 (44-26-13-09) Kuparuk State 22-11-12 Sag Delta #5 (36-12-15) Sag Delta #1 (33-12-16) No pictures, ran out.of film Sag Delta #2A (10-11-16) " " " " " " Sag Delta #3 (35-12-16) " " Sag Delta .#4 (34633) " " Sag Delta #7 " " Sag Delta #8 " " Sag Delta #9 .' " " Sag Delta #10 " ". MP Tract Well 32-30-11-13" " Niakuk #lA (26-12-15) Niakuk #2A (23-12-15) Chevron Tract Well (23-18-11-12) II II II II II II II II II II II II II II II II II II II II II II II II 11 II II II In summary, I inspected the above listed suspended locations for clean-up, well signs, and pit conditions. 02-001 A(Rev.10/79) Susp~ ,ed Well and Location Repc 20 AAC 25, ARTICLE 2 FILE INFORMATION Operator Addre s s Surface Location of'Well / 7~2~ Ft. ~ /~'"~ L, L~'4%~ Sec. 123, T // ~q/ , a/z ~ , Permit No F~. ~r~</ m API No. Lease Name ~M.. Unit or Well No.--~% Field & Pool ~` ~,:-~?'74~ Condition of Pad Condition of Pits Well head - Ail outlets plugged Well sign - Attached to well head Attached to well guard Attached to Information correct ~ No Ye s d~ Cellar - Opened Yes No Rat Hole Open Fi 1 led Ye s No Fi 1 led Covered Yes No Covered WaterWell - Plugged off Exp la na ti on Yes ',. ~ Ye?s No PhotOgraphs taken to verify above conditions~[[%~_.~$) No Explanaton Work to be done to be acceptable ~ _,~_ This well and location is (acceptable) (unacceptable) to be suspended for the period o 19 ~.~.thru ..... Date: ~.~: classified as Revised 8124/82 ,~-' STATE OF ALASKA _, ALASKA _ANDGASCONSERVATIONC 'MISSION SUNDRY NOTICES AND REPORT ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator 7. Permit No. Sohio Alaska Petroleun ~y 76-9 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50- 029-20192 4. Location of Well At surface: 1742' NSL, 744' EWL, Sec. 23, TllN, R12E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 64' AMSL 6. Lease Designation and Serial No. ADL 28263 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number Kuparuk State 22-11-12 11. Field and Pool Pr~3_dhoe Bay Prudhoe Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: Request extension under {Submit in Triplicate) 20 AAC 25.170(b) 1,2,3 Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other ]~ Pulling Tubing (Note: Report multiple completions on Form 10`407 with a submitted Form 10-407 for each completion,) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Reason for extension: This well was recompleted in 1980 as an observation well. Approved Copy Returned 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title District Drilling Engineer The space b iley 'AUG - · ~.:',Ska 0il &,,Gas Date 7'3 C°nditi°ns°fAppr°val'ifanYThis location was inspected by our representative on August 27, 1982 and clean up was found to be satisfactory for a suspended loctioan. A subsequent inspec- tion will be necessary by August 1983. By Order of Approved by ~V I~,~,~ ~ ~,~tTI~ COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 July 30, 1982 Mr. C. V. Chatterton Alaska Oil & Gas ConServation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: In compliance with State Regulation 20 AAC 25.170, attached are Forms 10-403, Sundry Notices and Reports on Wells, for the following wells. These notices request that the wells remain in suspended status. BP 41-33-12-13 BP 22-33-11-13 Term Well B (22-20-11-13) Term Well C (34-03-11-12) Chevron Tract Well (23-18-11-12) MPC Tract Well (21-03-10-12) PBU ~ 43-31-11-13 MPC 11-33-11-12 Getty State #1 (02-10-13) MP Tract Well (32-30-11-13) pBu MP 22-31-11-13, No. 2 West Sak 25645 #9 West Sak 25548 #11 West Sak 25655 #14 West Sak ~16 West Sak #17 %KuparukState 22-11-12 Sag Delta #1 (33-12-16) Sag Delta #2A (10-11-16) Sag Delta #3 (35-12-16) Sag Delta 34633 #4 Sag Delta #5 (36-12-15) Sag Delta #7 Sag Delta #8 Sag Delta #9 Sag Delta #10 Niakuk #lA (26-12-15) Niakuk #2A (23-12-15) Alaska Island #1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO,v, MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. Sohio Alaska Petroleum Company 76-9 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-20192 4. Location of Well OTHER At surface: 1742' NSL, 744' EWL, Sec. 23, TllN, R12E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 64' AMSL I6. Lease Designation and Serial No. ADL 28263 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number Kuparuk State 22-11-12 11. Field and Pool SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: :Request, extension under (Submit in Triplicate) 20 A_AC 25.170(b) 1,2,3 Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other ]~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Reason for extension: This well was recompleted in 1980 as an observation well. , ~Ipprovec~ Copy Returm?J 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~~ Title Distr'ict Dr-i_]_ling ]~q_gineer The space below for Commission use :Ro H. ]~l~iley ',i.,(,' % . = "~ ' ' Date 7'.~ C°nditi°ns°fAppr°val'ifanYTbis location was inspected by our representative on August 27, 1982 and clean up was found to be satisfactory for a suspended loctioan. A subsequent inspec- tion will be necessary by August 1983. :¢;"' Sid¢~'~] By Order of ,i.[ ~. , I~1~ I Approvedby n~ ~%~ ~.,.,, COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Date ............. Submit "~ntentions .... - --PI'cate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY October 27, 1981 3111 "C" sTREET ANCHORAGE, ALASKA TELEPHONE (907) 276-511 I MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage~ Alaska 99501 Attn: Mro Ho H. Hamilton Gentlemen: Kuparuk Statq (22-11-12) Enclosed,' in duplicatew is Form 10-407, RecompletJ.on Re.port, for the above-named well together with the Well History, · . This well has been suspended as a pressure observation we]./ for the western side of the Prudhoe Bay Field., GJP:ja Enclosures Well File #17 Geology . ALAsKA.~, . ' STATE OF ALASKA ' L AND.GAS CONSERVATION C'~,;,MISSION WELL CO PLETIO OR RECO PLETIO I R PORT A ;D LOG -1. Status of Well o ! · . -.. ..'. .o OIL [] GA'S [] SUSPENDED -~J ABANDONED E] SERVICE [] Classification of Service Well Obseruation . Name of Operator Sohio Alaska P~troleum Company 3. Atilt'ess Pouch 6-612, Anchorage, Alaska 99502 4~ Location of well at surface 1742' NSL, 744' EWL, Sec. 23, TllN', .R12E, UPM At Top Producing Interval 3089' NSL, 2286' WEL, Sec. 22, 'TllN, R12E, UPM At TOtal Depth 7. Permit Numbe¢ 76-9 8. APl Number so- 029-20192 9. Unit or Lease Name . Prudboe Bay Unit 10. Well Number :. Kuparuk St. 22-11-12 ' 11. Field and Pool .. Pr udhoe Bay :: 3134.~.iNSL,i 2387' Tal]~, Sec. 22/, TllN, R12E~. Ut~ .5. Elevation in feet {indicate KB, DF, etc.) /6. Lease Designation and Serial No. PJ:u(~ho~ Oil ~oo]. " KBE = 64' AMSL 147451. (surface) 28263(bottomhol~) · '3/8/76 I 5/9/76 !m7/26/81 I feelMSL ! one ..,,. ( o+Tvo i ,". ",u, ,.C, 10192'~ 9192'~]10093'~ 9112'~IYES~ NO~ I ' 1991. ice'MD, J 1950' '. 22. Type El~tric or Other Logs Run · gE~L/C~/GR, s~tralg, .~, gradio 23. CASING, LINER AND CEMENTING RECORD CASING SIZE WT. PER FT. GRADE 30" 156~ LP 20" .. . 94~ H-40 13 3/8" 7" , ,,72~ 29~ N-80 Soo-95 SETTING DEPTH MD 'OP BOTTOM - Surface 71' Surface 735' Surface 2723' surface 10172' 24. Perforations open to Production (MD+TVD of Top and Bottom and --inlterval, size and number) : - {i.~.MD . _.' ~/-D' - Top' 9832 ' 8895 ' Prudhoe Oil Pool: Bottom; 9935' 8980.~ 9832-9845'BKB 0.5"@4sPf (Ref.BHCS/GR, 5/i0}76; 9862-9892'BKB '". 8spf( -'" ....... ;~ "'"' ... "- "--'-.?':~' , ) 9910-9935'BKB " 8spf ( ; " ) . · . HOLE SIZE 27. Date.Fi~s~ Pr°d6ction '- - '7/16/81 Date of Test 7/16-26/8] Flow Tubing - Press. 174 28. 36" 17 1/2" 8 1/2" CEMENTING RECORD 125 sks Permafrost 4000 sks Permafrost 5000 sks Permafrost AMO{JNT PUl_LED 500 sks Class G 25. ,": , ~ -JFUBI NG RECORD , SIZ. E . i DEPTH SET (MD) PACKER SET (MD) 4 1/2" . I" 9657' ' 9579' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. - ~-~PTH INTERVAL (MD) AMOUN'I- & KIND OF MATERIAL USED 9860-9935' 200 sks Class G w/1% frictio~ reduCer *'" 't Me~h°d °f' Operati°rt~(Fl°wing' gas lift, etc.). ' ' ......:"" .... : Fl~:~i ' ' ' .. Hours Tested IPRODUCTION FOR IOI L-BBL GAS-MCF .77m ':~' -'-ITESTPERIOD '1~'--t' 2650 . 1244 Casing Pressure .. ICALCULATED ~l OIL-BBL , GAS-MCF zero 'I~.-HOUAR'A~E [." 900 : ' 414 CORE DATA i CHOKE S,ZE I SAS-O,,_ RATIO ] 1" · I 566'SCF/S~' IOil- GRAvITY-APl (corr) - · I 22.3oAPI '@ 60oF' ' WATER-BBL 25 WATER-BBL 9 Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None GE~iLOGIC MARKERS FORMATION TESTS o , NAME ..... ', ~ Include interval te~ted, pressure data, all fluids recovered MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. ~ ' ~r Cretac~s ~st in P~~rost ~or Cretac~s 5787' 5787 ~ ~ o~ Ku~uk 6236' 6235' Base o~ Ku~ruk 6397' 6197 ~ ' '- ~tal ~p~ 6550' 6550' .. - . . ... . .' .. ., ., . . , . . .. . .. : ~oll Histom · " Sig' ' _ ~ ~ ~~ . ~itm District: Field D~,~. / INSTRUCTIONS -: . _ . . . General: This form'is designed for submitting a complete and correct Well completion reporl: 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, sait 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 ~neasurements 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 1he in~erva!?~R@rted in item' 2.7. Submit a separate form for each additional interval 1.o be separately pro~e~,~;~h~ 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 ad¥1~'blfiple;~t~e:cement- ' lng and the ~ocation of the cementing tool, . Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic'Pump, Submersible, Water jection, Gas Injection, Shut-in, Other-explain. KUPARUK STATE' (22-11-12) WELL HISTORY RecomPlet[on % May_, 1980 Drilled Cement from 9787' to 9~68' 9869' to 9943' cleaned out- to PBTD at 10093'. Pressure tested.casing to 1000 psi, okay. Observed well; no flow. Changed well over to 9.6 ppg. NaC1. Pressure tested well to 1000 psi, did not hold. Set RTTS .at 6064'. Pressure tested DP x 7" annulus to 1500 psi. with 7" x 13 3/8" annulus open. Got returns of diesel in 7" x 13 3/8" annulus. Set RITS at 5691'. Pressure tested DP x 7" annulus. Pressure decreased to 1300 psi. Set RTTS at 6064'. Pressure tested to 1500 psi. Pressure decreased to 1000 psi. Closed top FO at 2257'~ Pumped acid across perfs at 9860' to 9935' with RTTS set at 9600'° Mixed and pumped 200 sks Class G cement with 1% friction reducer. Did hesitation squeeze with maxi- mum squeeze pressure at 4200 psi. Cleaned out cement to 10093'. Changed over to clean NaC1. Tested 7" casing to 1000 .psi, no leaks. Ran spectrolog, CBL/VDL/CCL/GR from PBTD to 8700'. Ran 4 1/2" tubing with production packer shoe at 9674'. Installed tree, displaced tubing to diesel, and set packer. Set "T" check in X nipple at 1991'. Set back pressure valve in tubing s.pool. Released rig at 0600 hours, May 9, 1980. July 1981 The back pressure valve and ,,T,, check were pulled and the following flowtests were performed: Initial F1°w period: 7/16/81 to 7/18/81 Time of production: Average oil rate: Average gas rate: Average water cut: Total oil produced: Avg. Gravity (°API)@ 60°F: 1793 min.' 689 BOPD N/A (separator bypassed) · 1% (difficult t~ obtain an accurate water cut due to completion fluid (NaC1) being cleaned out of wellbore)(at surface) 857.5 bbls. -. 22.3° Avg. wellhead flowing pressure: 174 psia Avg. wellhead flowing temp: .' 42°F Perforations: 9862' -19892' and 9910' -9935' BKB Second Flow Period: 7/21/81 to 7/22/81 Time of production:. Average oil rate: Total oil produced: Average gas rate: Total gas produced: Average GOR: Average water cut: Avg. Gravity (oAPI) @ 60°F: WHFP: 2182 min. 83J.5BOPD' 1263 bbls. 414MSCF/day 714MSCF 566 SCF/STB 0-1% 23~4o 214 psia an~hora.q-e Perforations: 9832' - 9845' 9862: - 9892', 9910' - 9935' BKB Third Fiow Period: 7/26/81 · Flo~ at 1200 BPD for 11 hours for 2XYI'--M logging° Total of 550 bbls. · flowed. Total Combined Flow Period Date flowed: Time of production: Average oil rate: Total oil produced: Average gas rate: Total gas produced: Average GOR: Average water cut: AVgo Gravity (OAPI) @ 60°F: 7/16/81' to 7/25/81 4635 min. (77.25 hfs 831 BOPD 2676 bblSo 414 MSCF/day 1.33 MMSCF 498 SCF/STB 1% at surface 23.'4o After completion of the testing, the top 8200' of tubing was displaced to diesel and the "T" check was reset° The well'is suspended as a pressure observation well for the western side of the Prudhoe Bay Field. SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 276-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 October 27, 1981 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive AnchOrage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Kuparuk State (22-11-12) Enclosed, in duplicate, is Form 10-407, Recompletion Report, for the above-named well together with the Well History. This well has been suspended as a pressure observation well for the western side of the Prudhoe Bay Field. GJP:ja Enclosures cc: Well File #17 Geology 'District Field Engineer RECEIVED OCT ° O0lL.lll,~.d0ri 0il & O~,s Cons. ~ -~, '~"" - Anchorafl~ STATE OF ALASKA ALASKA C,__ AND GAS CONSERVATION CO,,,,MISSION 'WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] Observation ... , 2. Name of Operator 7. Permit Number Sohio Alaska Petroleum Company 76-9 3. Address -- 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 s0-029-20192 4. Location of well at surface 9. Unit or Lease Name 1742' NSL, 744' EWL, Sec. 23, TllN, R12E, UPM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 3089' NSL, 2286' WEL, Sec. 22, T11N, R12E, UPM Kuparuk St. 22-11-12 At Total Depth 11. Field and Pool 3134' NSL, 2387' WEL, Sec. 22, TllN, R12E, UPM Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Oil Pool KBE = 64' AMSLI 47451 (surface) 28263(bottomhol_=) 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 3/8/76 5/9/76 7/26/81I feet MS LI QP.e 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 10192'MD 9192'TVD 10093'MD 9112'.TVD YES~ No E~] 1991 feetMD 1950' 22. Type Electric or Other Logs Run CBL/VDL/CCL/GR, spectralog, TDT, gradio ,, 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 30" 156# LP Surface 71' 36" 125 sks Permafrost 20" 94# H-40 Surface 735' 26" 4000 sks Permafrost 13 3/8" 72# N-80 Surface 2723' 17 1/2" 5000 sks Permafrost 7" 29# Soo-95 Surface 10172' 8 1/2" 500 sks Class G ,, 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD .... interval, size and number) ~JD r~FrV-D SIZE DEPTH SET (MD) PACKER SET (MD) Prudhoe Oil Pool: Top: 9832' 8895' 4 1/2" 9657' 9579' Bottom: 9935 ' 8980 ' . 9832-9845'BKB 0.5"@4spf (Ref.BHCS/GR, 5/10/76) 26. ACID, FRACTURE, CEMENT sQuEEzE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED` 9862-9'892'BKB " 8spf( " ~ ) 9860-9935' 200 ..sks Class G w/l% frictior. 9910-9935'BKB " 8spf( " ) i reducer · 27. PRODUCTION TEST Date First ProductiOn I Method of Operation (Flowing, gas lift, etc.) 7/16/81 J FlOWing .. Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-McF WATER-DEL CHOKE SIZE GAS-OIL RATIO 7/16-26/81 77 TEST PERIOD ~ 2650 1244 25 1" 566 SCF/STB Flow Tubing CaSing ~ressure CALCULATED OIL-DEL GAS-MCF WATER-DEL Gl L GRAVITy-APl (corr) Press. 174 ~ zero 24-HOUR RATE'~ 900 414 9 22.3OA~I @ 600~ 28. CORE DATA ,, ,, Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Upper Cretaceous GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH BKB ~rmafrost Lower Cretaceous Top of Kuparuk Base of Kuparuk Total Depth BKB Lost in Pi 5787' 6236' 6397' 5787' 6236' 6397' 6550' 30. 6550' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR,and time of each phase. 31. LIST OF ATTACHMENTS WelTsherebycer{~fy/ha t~efor~go~ngis~'e 1 Historv~ ' and correct to the best of my knowledge Title District Field Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show 'the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- 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". KUPARUK STATE (22-11-12) WELL HISTORY Recomple t ion \ May, 1980 Drilled cement from 9787' to 9868', 9869' to 9943'. Cleaned out to PBTD at 10093'. Pressure tested casing to 1000 psi, okay. Observed well; no flow. Changed well over to 9.6 ppg. NaC1. Pressure tested well to 1000 psi, did not hold. Set RITS at 6064'. Pressure tested DP x 7" annulus to 1500 psi with 7" x 13 3/8" annulus open. Got returns of diesel in 7" x 13 3/8" annulus. Set RITS at 5691'. Pressure tested DP x 7" annulus. Pressure decreased to 1300 psi. Set RTTS at 6064'. Pressure tested to 1500 psi. Pressure decreased to 1000 psi. Closed top FO at 2257'. Pumped acid across perfs at 9860' to 9935' with RITS set at 9600'. Mixed and pumped 200 sks Class G cement with 1% friction reducer. Did hesitation squeeze with maxi- mum squeeze pressure at 4200 psi. Cleaned out cement to 10093'. Changed over to clean NaC1. Tested 7" casing to 1000 psi, no leaks. Ran spectrolog, CBL/VDL/CCL/GR from PBTD to 8700'. Ran 4 1/2" tubing with production packer shoe at 9674'. Installed tree, displaced tubing to diesel, and set packer. Set "T" check in X nipple at 1991'. Set back pressure valve in tubing spool. Released rig at 0600 hours, May 9, 1980. July 1981 The back pressure valve and "T" check were pulled and the following flowtests were performed: Initial Flow Period: 7/16/81 to 7/18/81 Time of production: Average oil rate: Average gas rate: Average water cut: Total oil produced: Avg. Gravity (oAPI) @ 60°F: 1793 min. 689 BOPD N/A (separator bypassed) 1% (difficult to obtain an accurate water cut due to completion fluid (NaC1) being cleaned out of wellbore)(at surface) 857.5 bbls. 22.3© Avg. wellhead flowing pressure: 174 psia Avg. wellhead flowing temp: 42°F Perforations: 9862' - 9892' and 9910' - 9935' BKB Second Flow Period: 7/21/81 to 7/22/81 Time of production: Average oil rate: Total oil produced: Average gas rate: Total gas produced: Average GOR: Average water cut: Avg. Gravity (OAPI) @ 60°F: WHFP: WHFT: 2182 min. 833.5 BOPD 1263 bbls. 414MSCF/day 714 MSCF 566 SCF/STB 0-1% 23.4© 214 psia 48OF Perforations: 9832' - 9845', 9862' - 9892', 9910' - 9935' BKB Third Flow Period: 7/26/81 Flowed at 1200 BPD for 11 hours for TDT-M logging. Total of 550 bbls. flowed. Total Combined Flow Period Date flowed: Time of production: Average oil rate: Total oil produced: Average gas rate: Total gas produced: Average GOR: Average water cut: Avg. Gravity (°API)@ 60°F: 7/16/81 to 7/25/81 4635 min. (77.25 hrs.) 831 BOPD 2676 bbls. 414MSCF/day 1.33MMSCF 498 SCF/STB 1% at surface 23.4° After completion of the testing, the top 8200' of tubing was displaced to diesel and the "T" check was reset. The well is suspended as a pressure observation well for the western side of the Prudhoe Bay Field. October 21, 1981 Mr. P. R. Judd. Manager Drilling Sohio Alaska Petroleum Company Pouch 6-612 Anchorage, Alaska 99502 Term Well B (22-20-11-13) Sec. 18, TllN, R13E, U~. Term Well C (34-03-11-12) Sec. 03, Tll~], R12E, UM. PBU ~P 43-31-11-13 Sec. 05, T10N, R13E, UM. MP Tract Well (32-30-11-13) Sec. 30, TllN, R13E, PBU MP 22-31-11-13 Sec 30, Tll~.~, R13E, UM. sec 23, TllN, R12E, UM. Dear Mr. Judd: We are returning the approved Form 10-403's (SUNDRY NOTICES) granting an extension of clean-up time for subject wells, con- sidering these ¥~lls as suspended wells. The presently held Form 10-407's (WELL CO~PLETION REPORTS) do not properly convey that these wells are in a suspended status since they also indicate an oil or service status. It is requested that you submit Form 10-407 for each of the above listed wells with the Item 1 (STATUS OF WELL) marked as "suspended" if this is to be the desired classification. Sincerely, Lonnie C. Smith: Commissioner Enc lo sure s · . LCS/JKT: be STATE ol ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION TO~ ~Hoy le H. chairman Hamilton~ Thru: Lonnie C. Smith ~ Commissioner FROM: Bobby Foste~~k Petroleum Inspector DAT[ FILl "JILl PHOI'xt[ l'qO SUBJ£CT September 11, 1981 Inspection of SOttIO's Suspended Locations Listed Below MOnday Apgust 31 Thru Wednesday S_.eptember 2: I traveled to Prudhoe Bay Monda~ August 31, 1981 where I met with Jack Barr, Judy Golding and Jerry Stegar, Sohio representatives and discussed the upcoming location inspection. Attached to this report are pictures of well heads, reserve pit, drilling pad, and a copy of surface suspension report. It is my recommendation to the commission that the following locations be accepted in regard to location clean-up, well sign placement, and pit condition. Mobil Phil lips Mobil Phil lips Mobil Phil lips Chevron Tract West Sak West Sak West Sak West Sak Mobil Phil lips Mobil Phil lips Mobil Phillips Term wel 1 Term wel 1 Getty State Niakuk Niakuk Ni akuk Niakuk Sag Delta Sag Delta Sag Delta Sag Delta Sag Delta Sag Delta Sag Delta 21-03-11-12 11-33-11-12 22-11-12 23-18-11-12 #9 #11 #16 #17 22-3 43-3 32-3 1-11-13 1-11-13 0-11-13 B C #1 #1 #lA #2 #2A #1 #2A #3 #5 #8 In summary, I inspected the above listed suspended locations for clean-up, well signs, and pit conditions. - r Surface Location'0f Weis 20 AAC 25.120: Dia. Steel Post (4"Min.) <:' ' ~..Ttc-n/~:' , Length (10 Min.) Height Above Final Grade~ Level~ (4' Hin') Top of Marker Pipe Closed with' Cement Plug Set: On Well Head , On Cutoff Casing Distance Below Final Grade Level Side Outlets: All Valves and Nipples Removed All Openings Closed L~--- , With Blinds ~ , With Cement INI:Oi!HATION I~EAI)WEI~I)E1) t) JRE(:'FELY TO M,'~RI.iE[< }'OS'I" (List h~ere Different from File Information) Operator / ~ Unit or Lease Name Well Number Ft. F L, Ft., F Screw Cap , In Concrete Plug Ft. in. , Surface Location of Wel. L: L, Sec , T , R Wel ds ~, Other :! :", / :,~ ,:? ~- 20 AAC 25.170: LOCATION CLEAN-UP ? PITS: :,,, ~. ' 'Filled In..~/: :':Liners Removed or Buried , Debris Removed SURFACE OF PAD AND/OR LOCATION: Rough Other , Smooth ~: , Contoured , Flat , Compacted CLEAN UP OF PAD AHD/OR LOCATI()N: Clean ~ ...... ', Pipe Scrap __, Iron Scral~_ Paper , Other Wo od , Mud , Cernent SbqlROUN1) IN3 AREA: Wooded , Brush Sand , Other , Tundra ~' , Grass , Dirt , Gravel CONDITION SURROUNDING AP, I'7,\: · ~.~ Clean k.~' , Trash frown Site Other , Tree~ and/or Brush from Clearing Si_re ACCESS ROAD: Dirt , Gravel ~'', Ice , Ortner COND£TION ACCESS ROAI) AND' SURROUt,~I)IN(;: ~ Clean .... ' , Rough , Smooth ~.~:"" , Trash frown Operations Trees and/or Brush from Clearing Road , Spoil from Clearing Road Other -; ,.,} REFLA1NING TO BE DONE: RECOMMENI) APPROVAL OF INSPECTED BY o5/26/8~ No Final Iuspection I)AT i£ , / . ; SOHIO ALASKA PETROLEUM COMPANY SOH I 0 CONF ! DENT IAL 3111 "C" S1REET ANCHORAGE, AtASKA '[ELEPHONE [907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 '~o: STATE Date: 8/27/81 ~ 1015 C SOHIO MAGNETIC LIS TAPE wing material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- N'13 /' Corrected LIS TaPe & Listing N-11 LIS Tape & Listing N-14 ' LIS Tape & Listing(Corrected) F-7,/; LIS Tape & Listing Y-10=' LIS Tape & Listing G-13'/ LIS Tape & Listing Kuparuk St.22-11-12 LIS Tape & Listing D-15 R-9 Y-12 J J-13 F-2 M-12 H'16'i LIS LIS LIS LIS LIS LIS LIS Tape & Listing Tape & Listing Tape & Listzng Tape & Listing Tape & Listing Tape & Listing Tape &:'.Eisting '. #61732 6/18/81 #2 '~ #61776 5/9/81 #1.--' #62007 7/7/81 #1 / #62036 7/21/81 #4 ~ #62042 7/18/81 HZ ~ #62043 7/23/81 #1 ~ #62045 7/26/81 #1 / #62051 6/27/81 #2 ~' #62052 7/24/81 #1 ~ / #62055 7/25/81 #2 #62056 7/30/81 #1 #62060 8/1/81 #1 / #62071 7/3i/8i #i ~- #62075 7/19/81 #1 / DATE Develop ogy Well Records, HQ 4-5 SOHIO ALASKA PETROLEUM COMPANY August 17, 1981 Mr. Lonnie Smith Alaska Oil & Gas Conservation Co~mission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Pk. Smith: In co~liance with State Regulation 20 AAC 25.170, attached are Forms 10-403, Sundry Notices & Reports on Wells, for the following wells. These notices request that the wells remain in suspended status. Term Well B (22-20-t1-13) Term Well C (34-03-11-12) Chevron Tract Well (23-18-11-12) MPC Tract Well (21-03-10-12) PBU MP 43-31-11-13 MPC 11-33-11-12 Getty State #1 (02-10-13) MP Tract Well (32-30-11-13) PBU MP 22-31-11-13, No. 2 West Sak 25645 #9 West Sak 25548 West Sak 25655 #14 West Sak ~16 West Sak #17 Kuparuk State 22-11-12 Sag Delta ~1 (33-12-16) Sag Delta #2 (10-11-16) Sag Delta #2A (10-11-16) Sag Delta #3 (35-12-16) Sag Delta 34633 #4 Sag Delta ~5 (36-12-15) Sag Delta ~7 Sag Delta ~8 Niakuk #1 (26-12-15)-abandoned Niakuk #lA (26-12-15) Niakuk #2 - abandoned Niakuk ~2A (23-12-15) Niakuk #3 (13-12-15) A!;~'3ki (ii! & (i~'~~, ,'i, ~,:;. ALASKA r~-q_ AND GAS CC~NSERVATION CG!.IL!IS$1ON SUiZDRY [. J'i'IC{F.S A!Ib WELLS DRILLING WELL [] COMPLETED WELL Lq O1 ItLR E; 2. l~ame o! Operator Sohio Alaska Petroleum Cc~T~m~ny_ 3. Address Pc~Jch 6-612, Anchoraqe, Alas_k___a_ 99502 4. Lock,ion ol Well At sur fa~.: 1742' ~L, 744' ~, Sec. 23, TllN, ~2E, ~I 5. Eleva¢on in feet (indicate KB, DF, etc.) KBE = 64' ~LSL 6. Lease Designation and Serial No. APL 28263 7. Pr,mit No. 76-9 S,. APl r~umber _? °_-_0 29_-20192_ 9. Unil or tca~,e Prudt~oe Bay Unit 10 Well Number ___K_ut~_:_ruk State 2~_-1~!__-.1_2_2___ 11. Field and Pool Pr udhoe Bay Prudhoe Oil Pool 12. Check Appropriate Box To Indicate Nalure of Notice, Report, or Other Data NOTICE OF INTENTION TO: l%?est extension u~der SUBSEOUENT REPORT OF: (Submi'l in Triplicate) 20 AAC 25.170(b) 1,2,3 (SubmltinPupiic~te) Perforate [] Aher Casing [] '. rerforatlons ~ Al~e, ing Cas,ng ~ Stimulate ~ Abandon ~ S~imulalion ~ Abandonmenl ~ Repair Well ~ Change Plans ~ Repairs Made ~ Other ~ Pull Tubing ~ Other ~ Pulling Tubing ~ (Note, Repor! multiple completions on Form 10-407 with a submitted Form 10-407 for each complelion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent da~es, including estimated dale of slartlng proposed'work, for Abandonment see 20 AAC 25.105-170). Reason for extension: This well was reccmpleted last year as an observation well. R t!: C t V E b 0il & (-;i.m (',c,,~. C0~mlis,sion Approved Copy Returned 14'lhereby~ti~r~°ing.~Eandc°rrectt°thebest°lmY kn°wl~gc' The space belo~ Jot Commission use R. H.~iley Co~di,lo~ oi App,o¥~,.i~ ~:' T~S ~s~n~d location ms i~c~d by o~ repre~n~tive on 09/01/81 and ~o cloan-up ms ~ound P~t ~n, ~e'mll h~d on, and ~ s~~en~ ~~on ~11 ~ neces~ by ~d-s~r 1982. / ................ STATE OF ALASKA ALASKA _ AND GAS CONSERVATION C IMISSION SU[..'DRY [ OTIiC[: S A£:D o,r, VJ L! S DRILLING WELL [] 2. Name of Operator Sohio Alaska ?etro]eum C~ny 3. Address :Pc>~ch 6-612~ /mchoraqe~ Alaska 99502 4. Location of Well At sur face: 1742' NSL, 744' EWL, Sec. 23, TllN, R12E, UPM COMPLETED WELL 53 011tLR u%~ 7. Pe,r'ni! No. 76-9 8. APl Number .??=~029_:20Z92 9. Unit or t~.ase Name Prudhoe Bay Unit 5. Elevallon in feet (indicate KB. DF, etc.) j 6. Lease Designation and Serial No. KBE = 64 ' AMSL J ADL 28263 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 10. Well Number __K__uparu_k _S_t_a_t_e__22-] 1-] 2 11. Field and Pool Pr udhoe Bay Pr udhoe Oil Pool NOTICE OF INTENTION TO: Request extension under SUBSEOUENT REPORT OF' (Submit in Triplicate) 20 AAC 25.170 (b) 1,2,3 (Submit in Duplicate) Perforate El Alter Casing [] '. Perforalions [] Stimulate [] Abandon [] Stimulation [] Repair Well [] Change Plans [] Repairs Made [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each complelion.) Alto, lng Cas,n Abandonmen! Other 13. Describe Proposed or Completed Operations (Clearly state all pertinenl details and give perzinen! da~es, including estimated da~e of starling ~ny proposed work, for Abandonment see 20 AAC 25.105-170). Reason for extension: This well was recompleted last year as an observation well. Subsecl~e~.t WorF. ,,~.~z on ~orm No. ------- Dated Approved Copy Returned 14. I hereby~t~re~oing.~u,,e and correct to the best of mY knowledge. ~/~_~////~ .... Cond.iom o~ App.o¥.L i~ ..v: T~S ~s~n~d lo~on ~s i~~d by o~ repre~n~tive on 09/01/81 and ~e clean-up ~s fo~d to ~ ac~p~ble. ~pro~l is gi~n to lea~ the pit ~n, ~e ~11 h~d on, and ~e ~llar ~n. ~is appro~l is ¢~n ~1 09/01/82. A ~~ent i~~on., ~11 .~ ne~s~ by ~d-~rsv1982.o,o~. of~~/~' / /~ COf,~MISSIONER lhe C o,~,m,~ion Da~e Rev. 7-1410 .41 and ".c,.,[~*equcn! t~, po, ti. ~,~ [)upl~c~le SOHIO COHF IDENTIAL SOHIO ALASKA PETROLEUM COMPANY ARCO TO: (-Marathon) SFO./UNIT / STATE ~! ..... - 311 1 "C" S'1REET ANCHORAGE. ALASKA 1ELEPHONE (907) 265-0000 MAIL' POUCH 6-612 ANCHORAGE, ALASKA 99502 Dahe: 8/21/81 C' ~1000 F REFERENCE: J/Th'P. SOHIO FINAL DATA CAsed hole final data following material is being- Submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- B-14 J D-3 ,~ F-2 F-7 J-13 u./ TDT-M (Sch) 7/30/81 #1 Spinner (Camco) 7/7/81 #-- TDT-M (Sch) 8/1/81 #1 TDT-M (Sch) 7721/81 #4 TDT-M (Scb) 7/30/81 #1 EPL (Sch) 8/3/81 #2 (Sch) 7/21/81 #1 (Sch) 7/19/81 #1 Kuparuk St.)TDT~M 22-11-12 c-/ ) EPL 11 5" 5" 5" 5" 5" . t ' - logY ~ecords June 4, 1981 ~oi_.1o Alaska Petroleu~'a Co~i~any Pouch 6-612 Anchorage, Alaska 99502 Re: Alaska Oil and_ Gas Conservation Con, mission Regulations Article 2, A~,..N~O~.~h~N~. AND PLU(]~ING, 20 AAC zD 120 ~LL an~t AB~DONP.~ ~ ~ ~.~A~KE 20 ?~AC 25 170 ~C~n~'~ c~ ..... Gentlemen: In regard to the above referenced regulations, your attention is called to an attached list o~ wells which, accor¢]in9 to our records, have not received, a final location inspection ancl approval of clean up. in compliance with 20 AAC 25.170 Section (a), "Within one year of suspension or abandonment of an on- shore 'well", all clean up work is to }~ finished. Sectior. (b) ?rovides the means for aD e×tepsion of time if a vali~ re~son e:~ists. Section (c) provides for on site insI~,ection. Consequently, we are presenting the follo%~ing list of your abandoned and/or suspend, ed ~el!s. ~any of these are no%~ ~ore than one },ear old and are not in compliance with regulations. Others should have the final insi~ction completed this %~hile ~eather ~r~.~its. This list covers the years 1975 to date. There ~ay be some earlier %~ells that also need inspec- tion. If you have any earlier wells to be inspected tills ~um~_ please infor~n us Therefore, ~.~e are requestin~, a schedule fron] you =~_oz- this sumr~r %¢hen our field, inspectors can accompany your representa- tives to these sites for the final clean up inspection. SOHIO ~SASKA PETROLEUM COMPANY ._.~u_pa rUk 22-11-i2 Niakuk # 1-A Niakuk ~ 2 Niakuk 92-A Niakuk ~ 3 Prudhoe Bay Unit 3-i0-12 Sag Delta #2 Sag Delta #3 Sag Delta #33-12-16 Sag Delta 28337 Sag Delta 34633 #4 W. Sak 25519 ~17 W. Sak 25548 W. Sak 25645 ~9 W. Sak 25655 ~14 (GETTY, SOHIO, OPR.) State %1 PLUGGED & ABANDONED Challenge Is. ~1 Niakuk # 3 Prudhoe Bay Unit Nomination 1 RD Prudhoe Bay Unit' TR i5-11-12 Reindeer Is. Strat Test 91 W. Sak 25667 #4 (BP/SOHIO) Kemik unit ~2 Niakuk .% 1 -;FO/StfMPC/AE: ;FO/ST/AEP: RCO/STATE: SOHIO ALASKA PETROLEUM COMPANY t ..... ] Ri~6,,?.,~'3 i ' ARCO EXXON MOB I L TO: PHILLIPS CHEVRON SFO REFERENCE: SOHIO & 3111 "C" STREET I ..... ~-"'- ~,' q c.,.,;::. '-' '~ TELEPHONE (907) 265-0000 ~-cON'FER~' ~ FILF: #61407 9/25/78' #61251 1/14/81 #61447 3/1/81 #1 SP 8700-10100 3/18/81 DNLL 9550-10200 4/2/81 ' MPC TRACT WELL MAGNETIC LIS TAPES & LISTINGS ol]owing material is being submitted herewith. Please acknowledge receipt by signing a of this letter and returning it to this office:- ** MP Tract;K~ll~(4~)31-11-13 Magnetic LIS Tape & Listing #61417 **'-MP Tract Well (13)15-11-12 Magnetic LIS Tape & Listing #61475 " / * C~ 3B Magnet±c LIS Tape & List±ng B-2 " " " " · ..... KU~ar~'k~St'~'-22-11-12_~---f~a'gnetic- ~"~ ~"~"~'~'~'-'-~ LIS Tape F-9 ~ Magnetic LIS Tape . 1~ Tract Well ((32)30-11x13 net±c LIS Tape & List±ne #61463(61345) 1/9/81~ #1,2&3 2/8/81 #3 3/18/81 #-- /~nchora~Jo .,. Carol Krieter Development Geology Well Records SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO-BP ALASKA PRODUCTION DIVISION ;~CO .... Chevroa ..___,___ -- TO: SFO/UNIT/STATE: Mobil __ .,, _u (-Marathon) Pt~ilJip~ ~__ , , ' ' ' '- ,_ _ . SFO __ . 3111 "C" STREF_,,k'-':' ANCHORAGE, AL'A{SK7~ '2'-ENG 'rE _EPHONE 190Zl2 :.0000 - _ mA~L: POUCH 6-6{12-' ANCHORAGE ALASKk9 · J"- I S 'AT Ti C-- ii/i3/80 #4~<CONFER: J FILF: REFERENCE: :i FO /UNIT / STATE : SOHIO FINAL CASED HOLE LOGS /- /~./ The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- B-4 Spinner 10/20/80 Hi D-10 EPL 10/28-30/80 Hi D-12 CCL/Perf. 10/21/80 #2 H-8 EPL 10/28-30/80 Hi Q-2 Spinner 10/30/80 #1 Q-2 Spinner 10/24/80 HI ~.~--_ ............. ~xP_~f. CCL 10/21/80 #1 ~'~uparuk 22-11-12~5,, Temp. Log 11/3/80 #1 5,I 5" 5'~ 2"/5" 5'~ 5" 5" 5'~ Carol Krieter Well Records 19 Alaska Oil & Gas Cons, Commission Anch0ra.q~ SOHIO ALASKA PETROLEUM cOMPANY Alaska Oil & Gas Conservation CQmmission 3001 Porcupine Drive Anchorage, Alaska 99501 ANCHORAGE, A~, TELEPHONE (907~265-01 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 9 /-c'ONF:_:~. Attn: Mr. H. H. Hamilton Gentlemen: ?i,f!,,.f:~,-~:.t~. .............. Ku~ 'State (22-11-12) Enclosed, in duplicate, is Form P-7, Recompletion Report the above-named well together with the Well History. for This well has been suspended pending perforation as an observation well. RHR:ja Enclosures cc: Well File ~17 Geology Yours very truly, District Drilling Engineer SUBMIT IN DUPL ~TATE OF ALASKA (see~ struct Ions on reverse side) OIL AND GAS CONSERVATION COMMITTEE Form P--7 WELL COMPLETION OR RECOMPLETION REPORT AND LOG* WELLL_J DRY F-"] b. TYPE OF COMPLETION: NEW I---! WORK DEEP-r---3 PLUG I---1 DIFF. WELLI I OVER [-"l EN L_I BACK.I I RESER.r--] Other Observation Other Observation 2. NAME OF OPERATOR Sohio A~aska Petroleum Cca~a~y 3. ADDRESS OF OPERATOR Pouch 6-612, Anchorage, Alaska 99502 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* At,ur,ace 1742' NSL, 744' EWL, Sec. 23, TllN, R12E, UPM At top prod. interval reported below 2982' FSL, 2288' FEL, Sec. 22, TllN, R12E, UPM At total depth 3134' FSL, 2387' FEL, Sec. 22, TllN, R12E, UPM 13. DATE SPUDDED 14. DATE T.D. REACHED 5/9/76 15. DATE COMP, SUSP, OR ABAND. 5/9/80 3/8/76 18. TOTAL DEPTH, MD & TVD 1119' DEPTHPLUG BACK MD & TVDi20. IFHowMULTIPLEMANY. COMPL., lnlq2'wnl ~q192'q~/T111009q'MD 9112'TVD I 22~ PI~ODUCING INTERVAL(S), OF THIS COMPLETION --TOP, BOTTOM, NAME (MD & TVD)* None 21. ROTARY TOOLS ~ta_! 5. APl NUMERICAL CODE 50-029-20192 6. LEASE DESIGNATION AND SERIAL NO. ADL 47451 (surface) ADL 28263 (bottomhole) 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME pt~]r]hc~_ R~y Unit 9. WE LL NO. Kuparuk State 22-11-12 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay, Prudhoe Oil Pool 1 . SEC., T., R., M., (8OITOM HOLE OBJECTIVE) Eec. 22, TllN, 'R12E, UPM 12. PERMIT NO. 76-9 16. ELEVATIONS {DF, RKB, RT, GR, ETC)' 117. ELEV. CASINGHEAD I 64' INTERVALS DRILLED BY CABLE TOOLS :23. WAS DIRECTIONAL SURVEY MADE Yes 24. TYPE ELECTRIC AND OTHER LOGS RUN CBL/VDL/CCL/GR, Spectrolog 25. CASING SIZE WEIGHT, LB/FT. 30" 20" 13 3/8" 7" CASING RECORD (Report all strings set In well) 26. LINER RECORD SIZE TOP (MD) I BOTTOM (MD) SACKS CEMENT* I 28. PERFORATIONS OPEN TO PRODUCTION (Interval, size and number) ! ~ADE i DEPTH SET (MD) I HOLESIZE ! CEMENTING RECORD 156# 71' 36" 125 sks P~rmafrost 948 I H-4~ I 735' I 26" 14000 sks Permafrost 72# I N-8° ! 2723' I 17½" 15000 sks Pet~afrost 29# I s-95 I 10172' 8¥' I, 500 sks Class G 27. SCREEN (MD} SIZE 4½" 9657' 29. AMOUNT PULLED TUBING RECORD DEPTH SET {MD) PACKER SET (MD) 9579' ACID,--SHOT, FRACTURE, CEMENT SQUEEZE, ETC. None DEPTH INTERVAL (MD) q860'-qq35' ' 30. PRODUCTION IAMOUNT AND KIND OF MATERIAL USED 200 DATE FIRST PRODUCTION DATE OF TEST. IHOURS TESTED I FLOW TUBING ICASING PRESSURE I PR ESS. 31. DISPOSITION OF GAS (Sold, used for fuel 32. LIST OF ATTACHMENTS Well History I PRODUCTION METHOD (Flowing, gas lift, pumping--size and type of pump) CHOKE SIZE I PROD'N FOR OIL--BBL. TEST PERIOD vented, etc.) I WE LL STATUS (Producing or shut-In) GAS--MCF. V~T~R,~BB;L-.. ~ ~ [GAS--OIL RATIO WATER-BBL. ] OIL GRAVITY-APl (CORR.) TEST WITNESSED BY 33. I~f certify that the foregoing and atta~;l~d Information Is complete and correct as determined from all available records. .~~S,GJNaED ~ t,tLEDistrict Drillinq Engineer ~ ~. H, Reiley *(See instructions and Spaces for Additional Data on Reverse Side) DATE INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item: 16: 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. Items 20, and 22: if this well is completed for separate production from more than one interval zone (multiple com- pletion), so state in item 20, and in item 22 show the producing interval, or intervals, top(s), bottom(s) and name(s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produced, showing the additional data pertinent to such interval. . . Item 26: "Sacks Cement"' Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, 35. GEOLOGIC MARKERS WATER AND MUD NAME MEAS. DEPTH !TRUE VERT. DEPT[ '"36. CORE DATA, ATTACH BRIEF DESCRIPTIONS OF LITHOLOGY, POROSITY, FRACTURES, APPARENT DIPS AND DETECTED SHOWSQF OIL, GAS OR WATER. ., KUPARUK STATE 22-11-12 WELL HISTORY RECOMPLETION May, 1980 Drilled cement from 9787' to 9868', 9869' to 99~3'. Cleaned out to PBTD at 10093'. Pressure tested casing to 1000 psi. Held okay. Observed well, no flow. Changed well over to 9.6 ppg. NaC1. Pressure tested well to 1000 psi. Did not hold. Set RTTS at 6064'. Pressure tested DP x 7" annulus to 1500 psi with 7" x 13 3/8" annulus open. Got returns of diesel in 7" x 13 3/8" annulus. Set RTTS at 5691'. Pressure tested DP x 7" annulus. Pressure decreased to 1300 psi. Set RT?S at 6064'. Pressure tested to 1500 psi. Pressure decreased to 1000 psi. Closed top FO at 2257'. Pumped acid across perfs at 9860' to 9935' with RTTS set at 9600'. Mixed and pumped 200 sks Class G cement with 1% friction reducer. Did hesitation squeeze with maximum squeeze pressure at 4200 psi. Cleaned out cement to 10093'. Changed over to clean NaC1. Tested 7" casing to 1000 psi, no leaks. Ran spectrolog, CBL/VDL/CCL/GR from PBTD to 8700'. Ran 4 1/2" tubing with production packer shoe at 9674'. Installed tree, dis- placed tubing to diesel, and set packer. Set "T" check in X nipple at 1991'. Set back pressure valve in tubing spool. Released rig at 0600~ · hrs, May 9, 1980. "soHIo PETROLEUM CoMPANy' Division of Sohio Natural Resources Company SOHIO--BP ALASKA PRODUCTION DIVISION TO: Mobil _ SFO/UNTT/STATE t co i_J = i COMM i iii. i' ~N.G I TELEPHO.E m07)~0~ ~~ MAIL: POUCH 6-612 I :~T.~T TEC~ ANCHORAGE, ALASKA B~T TEc ~ } FILF: 7/30/80 #283 t i _ SFO/UNIT/STATE: REFERENCE: SOHIO CASED HOLE LOGS e following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- - Sp±nner Survey X-9 Temperature Survey 5/6/80 #l 5" 7/8/80 #1 5" 7/10/80 #4 5" Carol Krieter Well Records 6 - 7' .... DATE 19 SOHIO ALASKA PETROLEUM COMPANY July 8, 1980 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 9 --I"'COM'M ~':... !, ~111 ,,c,, s, _T,~.E.E~T..I' .J_2~ TELEPHONE (907) 265-0 100[.._~.~G ~ ~,~ ] GEOL ~ 2 GEOL I 3 ~EOL = [-STAT TLC ' ' ~I-STAT TLC ~ '~ID~T~ CONFEE: FILF: Alaska Oil & Gas Conservation ~ssion 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Well: KaparukSt. (22-11-12) Enclosed, in duplicate, is Form P-7, Completion Report, for the above-namedwell together with the Well History, This well has been suspended pending perforating operations below the OWC. RHR:GK: ta Enclosures cc: Well File ~17 Geology Yours ver~ truly, Form P--7 SUBMIT IN DUPI TE* STATE OF ALASKA (See other I,~ structions on reverse side) OIL AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOIVIPLETION REPORT AND LOG* WELLI I b. TYPE OF COMPLETION: NEW r-'-I WORK~ DEEP-i---I PLUG ~ DIFF. I---'] WELLI I OVER ~ EN I I BACKI I RESER.I I Other Pressure Observa- Other Recompletion 2. NAME OF OPERATOR Sohio Alaska Petroleum Company 3. ADDRESS OF OPERATOR Pouch 6-612 Anchorage, Alaska 99502 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* At surface 1742'NSL, 744EWL, Sec. 23, TllN, R12E At top prod. interval reported below At total depl~h 3134'NSL, 2397'WEL, SeC. 22, TllN, R12E 13. DATE SPUDDED 114. DATET.D. REACHED i15. DATECOMP, SUSP, ORABAND. 3/8/76I 5/9/76'1 Susp. 5/9/80 10 9 ~0093 ND, 9093 22. PRODUCING INTERVAL(S), OF THIS COMPLETION - TOP, BOTTOM, NAME (MD & TVD)* 5. APl NUMERICAL CODE 50-029-20192 ADL 28263 bot. hole loc. 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Pr~dhoe Bay Unit 9. WELL NO. Kuparuk St. (22-11-12) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay, Prudhoe Oil Pool 1. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) ;ec. 22, TllN, R12E, UM Alaska 12. PERMIT NO. 76-9 23. WAS DIRECTIONAL SURVEY MADE ~$ 24. TYPE ELECTRIC AND OTHER LOGS RUN SpectraloD, CBL/VDL/OCL/GR from PBTD to 8700' 25. CASING RECORD (Report all strings set in well) CASING SIZE 30" 26. 3/8" 7" i WEIGHT, LB/FT. GRADE DEPTH SET (MD) I HOLE SIZE / / 735' 72 ~-80 Bqtt. 2723' 17½" 29 ~-95 B~tt. 10172' 8½" LINER RECORD SIZE TOP (MD) BOTTOM (MD) SACKS CEMENT* 28. PERFORATIONS OPEN TO PRODUCTION (Interval, size and number) NOI~3 30. CEMENTING RECORD 125 sks. Permafrost 4000 sks. Permafrost 5000 sks. Permafrost AMOUNT PULLED SCREEN (MD) 500 sks. Class G. SIZE DEPTH SET (MD) 4½"12.6# 9656 PACKER SET (MD) 9579 29. ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) I AMOUNT AND KIND OF MATERIAL USED 9860 ' - 9935' ] Acidize Perforations 9860' - 9935' I Squeeze ~erfs. with 200 sks. I Class G Cement PRODUCTION DATE FIRST PRODUCTION DATE OF TEST. IHOURSTESTED ICHOKE SIZE I PROD'N FOR TEST PERIOD FLOW TUBING ICASlNG PRESSURE ICALCULATED i OIL--BBL. PR ESS. 24-HOUR R~TE 31. DISPOSITION OF GAS (Sold, used for fuel, vented, etc.) PRODUCTION METHOD (Flowing, gas lift, pumping--size and type of pump) I WELL STATUS (Producing or I shut-In) OIL-BBL. GAS--MCF. iWATER-BBL. [GAS-OIL RATIO I I i' TEST WI,TNFSSED 32. LIST OF ATTACHMENTS 33., hereby certify ~~~ ,~~~lplete and correct as determined from ali available records. ~:'' SIGNED ~TITLE Dist~ic~c Drilli~q ~g~r DATE R. H. B~ley ~ ' *(See instructions and Spaces for Additional Data on Reverse Side) 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: 16' 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. Items 20, and 22: If this well is completed for separate production from more than one interval zone (multiple com- pletion), so state in item 20, and in item 22 show the producing interval, or intervals, top(s), bottom(s) and name(s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produced, showing the additional data pertinent to such interval. Item 26: "Sacks Cement"' Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). ,, 34. SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, 35. GEOLOGIC MARKERS WATER AND MUD NAME o MEAS. DEPTH TRUE VERT. DEP'[' 36. CO.RE DATA, ATTACH BRIEF DESCRIPTIONS OF LITHOLOGY, POROSITY, FRACTURES, APPARENT DIPS AND DETECTED SHOWS OF OIL, GAS OR WATER. ,, WELL'KUPARUKST. 22-11-12 WELL HISTORY April, 1980 Accepted rig at 0001 hours, April 25, 1980. Installed and tested BOPE. Drilled out cement frc~ 37' to 67' and 2380' to 2465'. Drilled on EZ Drill at 2465'. Drilled out cement frc~ 3246' to 3321'. Drilled on EZ Drill at 3321' Drilled out cement from 3322' to 3408'. Drilled EZ Drill at 3408'. Dril!~cement stringers from 8435' to 8676'. Drilled cement stringers from 9287' to 9339'. Drilled EZ Drill pieces at 9341'. Washed to 9683'. May, 1980 Drilled cement from 9787' to 9868' and 9869' to 9943'. Cleaned out to PBTD at 10093'. Pressure tested casing to 1000 psi. Held okay. Observed well, no flow. Changed well over to 9.6 ppg. NaC1. Pressure tested well to 1000 psi. Did not hold. Set R/TS at 6064'. Pressure tested DP x 7" annulus to 1500 psi with 7" x 13 3/8" annulus open. Got returns of diesel in 7" x 13 3/8" annulus. Set RITS at 5691'. Pressure tested DP x 7" annulus. Got returns in 7" x 13 3/8" annulus. Set RITS at 3977'. Pressure tested DP x 7" annulus. Pressure decreased to 1300 psi. 'Set RTTS at 6064'. Pressure tested to 1500 psi. Pressure decreased to 1000 psi. Closed top FO at 2257'. Pumped acid across perfs at 9860' to 9935' with RUES set at 9600'. Mixed and pumped 200 sks Class G cement with 1% friction reducer. Did hesitation squeeze with maximum squeeze pressure at 4200 psi. Cleaned out c~t to 10093'. Changed over to clean NaC1. Tested 7" casing to 100.0 psi, no leaks. Ran spectrolog, CBL/VDL/CCL/GR from PBTD to 8700'. Ran 4 1/2" tubing with production packer shoe at 9674'. Installed tree, displaced tubing to diesel, and set packer. Set "T" check in X nipple at 1991'. Set back pressure valve in tubing spool. Released rig at 0600 hours, May 9, 1980. SOHIO ALASKA PETROLEUM COMPANY May 29, 1980 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Kuparuk State 22-11-12 Enclosed, in duplicate, is Form 10-404, Monthly Report of Drilling and Workover .Operations, for the above-named well for the month of May, 1980. RHR: ja Enclosures cc: Well File ~17 Yours very truly, R. H. Reiley District Drilling Engineer Form No. 10404 REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. APl NUMERICAL CODE 50-029-20192 6. LEASE DESIGNATION AND SERIAL NO. ADL 28263 1. 7. IF INDIAN'ALOTTEE OR TRIBE NAME WELL WELL OTHER Observation 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Sohio Alaska Petroleum Company Prudhoe Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. Pouch 6-612, Anchorage, Alaska 99502 Kuparuk State 22-11-12 4. LOCATION OF WELL At surface: 1742' NSL, 744' EWL, Sec. 23, TllN, R12E, UPM 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay,Prudhoe Oil Pool 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 22, TllN, R12E, UPM 12. PERMIT NO. 76-9 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES 1N HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Y~y, 1980 Drilled cement from 9787' to 9868' 9869' to 9943' Cleaned out to PBTD at 10093' , · · Pressure tested casing to 1000 .psi. Held okay. Observed well, no flow. Changed well over to 9.6 ppg. NaC1. Pressure tested well to 1000 psi. Did not hold. Set RSTS at 6064'. Pressure tested DP x 7" annulus to 1500 psi with 7" x 13 3/8" annulus open. Got returns Of diesel in 7" x 13 3/8" annulus. Set RITS at 5691'. Pressure tested DP x 7" annulus. Got returns in 7" x 13 3/8" annulus. Set RITS at 3977'· Pressure tested DP x 7" annulus. Pressure decreased to 1300 psi. Set RT~S at 6064'. Pressure tested to 1500 psi. Pressure decreased to 1000 psi. Closed top FO at 2257'. Pumped acid across perfs at 9860' to 9935' with RITS set at 9600'· ~xed and pumped 200 sks Class G cement with 1% friction reducer. Did hesitation squeeze with maximum squeeze pressure at 4200 psi. Cleaned out c~t to 10093'. Changed over to clean NaC1. Tested 7" casing to 1000 psi, no leaks. Ran spectrolog, CBL/VDL/CCL/GR from PBTDto 8700'· Ran 4 1/2" tubing with production packer shoe at 9674'· Installed tree, displaced tubing to diesel, and set packer· Set "T" check in X nipple at 1991'· Set back pressure valve in tubing spool. Released rig at 0600 hours, ?~ay 9, i~80. GK: ja 14. I hereb~?i~ SIGNE~... ~ei~e.v ~ TITLE District Drillinq ~g~e~x~ ~, ~ · g~ NOYE-~eport on this ~orm is raquired ~or eaeh~lenda~ month, ~a9ardl~ of tha status ot operations, and mu~ ba iliad in du~licata ~ith th~ oil and oas conservation ~ommittee by the ~5th o~ the sueeeedin9 month,unl~ othar~ise diract~. SOHIO ALASKA PETROLEUM COMPANY May 15, 1980 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton ANCHORAGE, A LA ~9~,.A TELEPHONE (907, 265. POUCH 6-61 MAIL: ANCHORAGE, ALASKA __~ ~II.F: Gentlemen: Well Kuparuk St. 22-11-12 Enclosed, in duplicate, is Form 10-404, Monthly Report of Drilling and Workover ..Operations, for the above-named well for the month of April, 1980. AMR:ja Enclosures cc: Well File ~17 Yours very truly, Austin Reid .Acting District Drilling Engineer [ .AY ! 5 Anr,;hm ak~,¢ Form No. 104,04 RL~'V'. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. APl NUMERICAL CODE 50-029-20192 6. LEASE DESIGNATION AND SERIAL NO. ADL 28263 1. 7. 1F INDIAN'ALOTTEE OR TRIBE NAME OIL [5] GAS 7~ WELL WELL OTHER Observation 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Sohio Alaska Petroleum Company Prudhoe Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. Pouch 6-612, Anchorage, Alaska 99502 Kuparuk St. 22-11-12 4. LOCATION OF WELL At surface: 1742' NSL, 744' EWL, Sec. 23, TllN, R12E, UPM 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay, Prudhoe Oil Pool 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 22, TllN, R12E, UPM 12. PERMIT NO. 76-9 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. April, 1980 Accepted rig at 0001 hours, 4/25/80. Installed and tested BOPE. Drilled out cement from 37' to 67' and 2380tto 2465'. Drilled on EZ Drill at 2465'. Drilled out cement frcm 3246' to 3321'. Drilled on EZ Drill at 3321'. Drilled out c~t from 3322' to 3408'. Drilled EZ Drill at 3408'. Drilled cement stringers frcm 8435' to 8676'. Drilled cement stringers from 9287' to 9339'. Drilled EZ Drill pieces at 9341'. Washed to 9683'. GK:ja 14. ' hereby ce, tify that the~7~.s tr~;n~correct Acting SIGNED · [~ i ~ ~ TITLE DS~g~ic~_ DrS1] 5n~ ~ n~TE AllSt, l n Hel fl ' ~ NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. Alaska Oil and Gas Conservation Commission Chairman of the Commi~£on Lonnie C. Smith Commissioner April 28, 1980 Harold R. Hawkins Petroleum Inspector~,w.>~.w To Witness: BOPE Test SOHIO ~obil ;- Phillips,- Socal Leases Prudhoe Bay Field. Prudhoe ~ Oil Pool Sec.22, TllN, R12E, UM Permit 76-9 Kuparuk State 22-11-12 April 24, 1980 - I left Anchorage at 3:30 PM by Alaska Airlines, A Sohio charter to Prudhoe Bay. The purpose of the trip was to witness a BOPE test on Sohio's Kuparuk well No. 22-11-12. When I arrived on the location, I met Garland Goodwyn, Supervisor for Sohio and RaY Wadly, Pusher for Nabors Rig No. 1-ES. Nabors was riggin up 1-ES and in the process of nippling up the BOPE's. A~ril 25, ~980 - I witnessed the test of the annular preventer and the choke manifold. The next test was on the upper pipe rams. The upper pipe rams and the test plug failed. April 26, lp8.0- A hanger type test plug was installed and upper pipe rams changed out. ~ BOPE tests was resumed at 5:00 AM and finished at 7:30 PM. I filled out an Alaska Oil & Gas Conservation Commission B.O.P.E. Inspection Report, which is attached to this memo. In summary: I witnessed a B.O.P.E. test on Kuparuk State, Well No. 22-~1-12. See remarks on BOPE Inspection Report. Attachment: 4/28/80 - 12:10 PM Kuparuk 22-11-12 Garland Goodwyn, Supervisor for Sohio on 1-ES, called. N2 bottles filled to 2200 PSI each, outside kill valve tested to 5000 PSI. O&G #4 4/s0 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Operator j"~/ ~ Well ~ ~ ~ ~/.*/ Location: Sec ~ Drilling Contractor Date F/~6' Representative Pe rmi't ff 2~ /.3~ Casing Set Rig ~/-~' Representative Location, General/W~~ Well Sign 4~ O' General Housekeeping_ Reserve pit O/~ Rig ~7~ Test Pres sure BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves ACCUMULATOR SYSTEM Full Charge Pressure ~6~'D LO psig Pressure After Closure /~D psig 200 psig Above Precharge Attained: ~ min~ sec Full Charge Pressure Attained: ~ min~ sec Controls: Master -'69 f~ R cmo 't e _~_./_'~ ___ B~l_i_n__d__s___s_w_i~c ]_~___ _c_q_v_qr Oj[_ Kelly and Floor Safety Valves H.C.R. Valve Kill Line Valves Check Valve Upper Kelly,~DO Lower Kelly~o Ball Type Inside BOP Test Pressure Test Pressure Test Pressure Test Pressure ~//~ Choke Manifold ~O Test Pressure No. Valves / ~ No. flanges / .~ D~J~]~_.~ W .3, ] $ ~z;~-6z&' Adjustable Chokes ~ ~ ~tf Hydrauically operated choke_~-_/9~f&~ Test Tim~ ~ .... ~.-~ ~-/-~ _-----~/U Test Results: Failures~ Repair or Replacement of failed equipment to be made within .... days and Inspector/Commission office notified· ~lSErlOUE1On ~ ~ ' ~ w- ' . orig. - AO&~C ~'~~,; ~0~ k k ~-' /LU~J~X~T~ ~' ........... ~g~m~r'~n '~ ~' ~ / ~.l~& V~~ ~IF~~p [~ZXL~P ~/~~./'~ CC Operator ~ ~ ~ '~rL~, ~, cc- su rv so O SOHIO ALASI(,A PETROLEUM COMPANY l { O,: . ~.. ~aska Oil & Gas Conse~ation Co~ssion 3001 Porkpie Drive ~chorage, ~aska 99501 [%1 "'t':' 31 'C" STRE ] Eh,IG . .. ANCHORAGE, A LASI<A~p~ t s GEOt ...... ~ STAT TEC -~, STAT TEC CONFER: FIL~: Attn: Mr. H. H. Hamilton Gentlemen: Attached are Sundry 'Notices to abandon the following wells located inside the Unit boundaries of the Prudhoe Bay Unit. Mobil-Phillips Kuparuk State #1 Kuparuk State 24-11-12 Kuparuk State 7-11-12 Kuparuk State 33-11-12 Hurl State 5-10-13 W. Kuparuk State 3-11-11 Also included is our Sundry Notice to complete Kuparuk State 22-11-12 for use as a pressure Observation well. PRJ: ja Enclosures cc: Well Files A. M. Skov, S.F. Yours very truly, SOHIO ALASKA PETROLEUM CO. P. R. Judd District Drilling Engineer For~ 10-403 REV. 1-10~73 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such prop0sals~) OIL ~ GAS r-] WELL Zl.~J WELL OTHER NAME OF OPERATOR Sohio Alaska Petroleum Company 3. ADDRESS OF OPERATOR Pouch 6-612, Anchoraqe, Alaska 4. LOCATION OF WELL At su trace 5. APl NUMERICAL CODE 50-029-20192 6. LEASE DESIGNATION AND SERIAL NO. ADL 47451 Surface Location ADL 28263 Bottc~hole Location 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit ,9. WELL NO. Kuparuk St. 22-11-12 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay,Prudhoe Oil Pool 1742' FSL, 744' FWL, Sec. 23, TllN, R12E, UM At T.D.: 3134' FSL, 2387' FEL, Sec. 22, TllN, R12E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) RKB = 64' 14. Check Appropriate Box To Indicate Nature of Notice, Re 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 22, TllN, R12E, UM 12. PERMIT NO. 76-9 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~] PULL OR ALTER CASING FRACTURE TREAT ~ MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE-' Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all 13ertlnent details, and give pertinent dates, including estimated date of starting any proposed work. This well was suspended 5/28/76. We propose to enter this well on approximately April 10, 1980 to complete for Sadlerochit Aquifer Pressure Observation Well. The present mechanical condition is as follows: 30" casing cemented at 71'; 20" casing cemented at 735'; 13' 3/8" casing cemented at 2723'; 7" casing cemented at 10172'; perfor- ations at 9860'-8990' and 9910'-9935'. Cement plugs in place 9810-9936'; 8460-8575'(BP), 3312-3420'(BP), and 2406-2429'(BP). The proposed ccmpletion is: 1. Drill out cement and cast iron plugs to PBTD of 10120'+. 2. Squeeze off existing perforations and test. Change well over to cc~pletion bline. 3. Perforate in water zone 10020'-10030'+. 4. Run 2 1/4" tubing with packer at 9700T, change tubing over to diesel and set packer. Well will be suspended with non-freezing fluids left through the permafrost and check valve installed in tubing belowthe permafrost. TITLE District Drilling Engineer DATE. 16. I hereby certify SIGNED (This space for State office u~e) //~! ? APPROVED BY ~ /~'~'~--<' , CONDITIONS OF APPROVAL, IF ANY.' TITLE DATE See Instructions On Reverse Side ORDER OF THE l)24~1B STATE ef ALASKA DEPAR'I%.IENT OF NATUP~AL RESOURCES Division of Oil and Gas ,. ~ FROM: TO: F-- ©. K. Gilbreth, Jr ~ Director ~~ Thru: Hoyle H. Hamilton /~£~ Chief Petroleum Engineer Harold R. Hawkins .... Petrote~ Inspector DATE "June 21, 1976 SUBJECT: Inspecting Diesel Leak, Hobil Oil, Co. Kuparuk State 22-11-12 U oT,~. PEP~-76-g Tuesday, June 1~5, 1976 - I departed Anchorage at 7:25 AH on ~!ien to Prudhoe Ba~, Le(~-P~-~ ~ on MoP.il chartered Twin Otter to 2£-11-12 U.~'to site. ~qet with Ken Sullivan, operator for Mobil. A loader bumped the fuel line that was used for rig fuel and cracked it which penetrated gravel in corner of pad ~hich in turn due to thawing got into .the lake and stream. ~,,!e went directly to where the creek crosses under the haul road about 3/4 mile due north from the lake and drill site. ! took one picture of the creek on the north side of the road. There v~as a very light sheen of diesel gettin~ by 3 pads that are on the south side of the road. Ken Sullivan had ordered more pads to be placed on the south side of~ the creek from. the road. These extra pa~]s seer~i to be catching the diesel now with a very light sheen in spots. Ken Sullivan and I ~ent to the drill site. I teok pictures of the location at the corner of the pad where the leak took place. The picture was taken from north to south on the east end of the south corner of the pad. There is a strip about 150' wide running southeast from the corner of the pad and 350' long to the lake, ~here some potholes have a diesel film and some don't - about a third of this area as I see it. The small lake has pads acrgss the south above the leak and has pads across the lake, north of the lake the ~ay the creek runs. Also they had pads running north and south around where the film was entering the lake. I suggested more pads where the fil~ entered! the lake and Ken Sullivan had this done and it seemed to contain the light fi lin. ~ suggested to Ken Sullivan to have a cat shove the gravel and snow to the permafrost up o~ the pad and haul it off which would [?~.ore than likely stop the penetration of diesel from the gravel in the corl]er of the pad. Ken Sullivan was very agreeable and had a cat operator do this After ~ravel snow on the corner of the pad was pushed out, I could find very little, if any~ diesel in the underlay. In sugary, I found that the diesel that leaked out from a cracked line ~ m~.~e and that the bumped by a loader was more like 25 ~allons from ~y esti ~t= operator was doin~ a fine job of getting it cleaned up and containinq the diesel in a small area. The operator has done everythinq to prevent any m~re seepage from spreading. From my estimation, ! figure that there ~.~ilt not be any da~ge to vegetation or ¥~ildlife. I have p~ctures to verify these s ta temen ts. / '! ix/ 5 NOBiL OTL_ CORPORA ALASKA · ,~u ~--~','~ AREA P. O. BOX ~ ~'~ T. A. ~ ~ COLORADO 802i7 D~N ~m R ~ TRANSFERRED TO: TR-~NSFERRED BY: · %:. R. L. Wood, Mc. bii.Oi-l-~2oreoration DATE' 6/1'7/76 _ Transmitted herewith is the foliowinq final well information o_n M_PS 'Kuparuk 22-11-12 ' ,%. - Survcy ~ TM ~ ~ . . ~ 4 pages of We~i History pages of Core Description + 7.P~?{~ a/ · Repos% Core Lab Core Analysis with Core Gamma ]Log '/1 Reverse 'Sepia of Mud Log '" /1 Eastman Directional Survey ~i%'ro ~A576 G0120 · _ /'"'2 Halliburton Report~DST ~i and DST ~2 1 ~-2 Camco Reports DST~-~i and DST ~_ · Each Reverse Reading Sepia ~ ~-: ~' · ~- o©;.,-u,~oerger Loqs:._ (total 8 ]:©~,~S_)_._ · '. DIL Runs i & 2, 2" & 5" ' GNL-GR Run 1,. 5" BHC Run '1, 2" & 5" ' FDC-GR Run 1, 5" GR Run 1, 5'; HDT Run 1, 5" -" A,~D RETU~,~ ORICT}f:V[, COPY PLEASE CH~,C~ Descriptors to include when applicable: 1. Number copies or copy numbers ~ype of print- Field or Final Type of copy: Film, Sepia, Blueline, Velum 4, Series, Sequence or Interval · RECEI\~D DATE: Mobil Oil Corporation June 17, 1976 P.O. BOX 5444 DENVER, COLORADO 80217 TELEPHONE (303) 572-3636 · State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99503 KUPARUK 22-11-12 PERMIT NO. 76-9 NORTH SLOPE, ALASKA Gentlemen: Attached is the well completion report of the Kuparuk 22-11-12 well on the North Slope. Yours very truly, W. G. Sole Area Engineer Alaska Producing Area PKP :mjh Attachment (2) Form P---7 %...- SUBMIT IN DUPL~i · ATE OF ALASKA str(~tiafiS on OIL AND GAS CONSERVATION COMMITTEE r~,,~-~ WELL cOMPLETION OR RECOMPLETiON REPORT:AND LOG:* ii WELL DRY Other ADDRESS OF OPERATOR Box 5444, Denver, Colo. 80217 ~ ~. · · . LOCATION Or WgLL .(Report location clearly and in accordance with any-State requirements)* at su~acel ,742' from south Tine & 744' from ~/est line: ~i Sec 23-TllN-R12E. U.~., Alaska at top prod. ,n;er,a, re~ortea ~e~o- 2982 from south line & 2288, from ~_a.~t line, Sec.22-TllN-R12E, U.M., AlaSka ,t tota,~z~, from south line & 2397' from east line Sec. 22-TllN-R12E, U.M., Alaska -.~ fa.'TYPE OF WEL~: OiL WEI,L b. TYPE OF COMPLETION: NEW [~ WORI, ~] DEBt'- ~ P[,UG ~ DIFF. ~ WELL OVER EN BACK RESVR. Other NAME OF OPERATOR ~ob~l 0~1 Cocpocat~on 8. AP1 NU1VLEd~ICJkL CODE 50-029-20192~ 47451-surface loc. ,_ADL 28263-bot.hole loc ?. IF IN-DIA~, ALLO~ OR TRIBE NAM~ II. - ~.1~ 8. UNIT,F~ OR LEASE NAJVIE Mobil-Phillips-Socal leases 9. WELL I~TO, Kuparuk 22-11'-12 10. Frond A~ID POOL; OR WILI3C"AT Prudhoe Bay fld. ,Prudhoe .[~' [l~l ~PO0 11. SEC., T., R., M., (BCYI~OM HOLE~ OBJIEC~IVE) Sec. 22-Tlt N-R12E U.M, Alaska 12. PERMIT NO. 76-9 3-8-76 [ 5-9-76 I 5-2~8-76~ Suspended !64' ~(RKB) ] 45' 18. 'l~(.y~ikL.~l~j~I~,~)~& TVD[19~PL}rrR¢.I~A~ ~ ~ & ~ ~, ~ ~LTmLE']CO~L.', [' ~{. ' INTERVALS D LLED - I ~ '/fflU ! / ~, qUO: I I~M.)._. / ~ow ~Y* : ] sOT,~ ~00LS ~ cx~ T0m.,S ~;192'(mvO) [2;406'~(1VU) I ' J' ~,,rfac~ tn mD ~. PRODUCING IN~VAL(S), OF ~IS CO~PETIO~--TO~, BOSOM, N~E (D AND ~}' [32. WAS DIREC~O~AL I I SURVEY ~DE Top- 9,860 (MD), 8,918 (TVD) Sadlerochit ~ yes Bot - 9,935' (MD), 8,980' (TVD) . .... j ~. ~ EL~O~R~C *~ o~=~ ~oos ~U~ D IL, GR-Soni c, GR-CNL'FDC, Di pmeter, Down' Ho 1 e .. . ~eophone survgy and side.watl;~cores. , . ~. CAS~G RECORD (Re. Pt all strings set in weld 20 "30 "c*~ s~z~ i15~I w~-~.94 LS/r~. I:iH_40'LPF ~*DSl I I} ! DEP~735,.71s~, ' (~"]{ 26"~°~6" s~z~:.'l]~125' SX cn~~Permafrost.~Eco~ ~OUNT ~ : ;4000 sx Permafrost 13-3/8~.,. 72 ] N80rB~tt 2723]' 17%" I..5000'sx Permafrost 7" [ 29 ~sg5-m~tt 10,172' ] 8%" ['500 sx Class G 26. " LINER RECO~ ' ' ' f [ 27.. "" TUBING ~aSIZ~ & TOP (5iD) [ ~OTTO~ (MD) SACKS C~{~T*~~ SC~ (~D) tSIZE E [ ' ' size and number) i ~'~~~ ] ' ~ [ D~ SET (~D) ~ PACKER SET (~D) , 28. PEKFORATIONS OP~ TO PR~DUC~ON (interval ' ' ' " ~ '- ' a 0'- 890' 9 0'-99ss' as') Placed cement plug across pecfs.~~ ii i i ii i i ~ %~ ~ " ' i i 30. PF, ODUCTION " r~r~.~,ma~.~ ~l~ ?'%Ii Ab,[~ f,~,~,,].r:, , DATE FIRST PIZODUCTiON ~ODUCTION ME'ii{OD (Flowing, gas lift, pump~g--size and type of prop) c, ~ ~¢~L~A~' (~6a~cing or 5-19-76 ', 12 hr.40 mi FLOW, TUBING cA~'NG PRESSERE ICALC~AT~ OI~BBL. GA~MCF. . :, WA~B~. lOlL GRAV~Y-~I (CO~.) ~ psi 31. DISPOSITION OF GAS (Sold, used for ]uel, vented, etc.) ~ ; ITEST WITNESSED BY burned LIST OF ATTACHMENTS ~. ' ....... []ectc~c logs, Uqcect~onal Survey,. ~ocma~]ofl test~cepocts, Mud Icg Conventional core description, side 33. I hereby certify th~.t the ~fegoing~nd attached information ts com~'lete and correct.as determined ~rom all:avallab~'~ records i r, ] INSTRUCTIONS General: This form is designed for subrnitting a complete and correct well completion report and log on all types of lands and leases in Alaska. item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- merits given in cther spaces on this form and in any attachments. Items :20, iincl ~2:: if this well is completed for separatc, production from rT~ore than one interval zone (multiple cdmpletior~), so state in item 20, and in item 22 show the prc. Juc~r'~g interval, or ir~tervals, top(s), bottom(s) and name (s) (if any} for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produceS, show- lng the additional data pert~nenl to such interval. Item:26: "Sacks Cement": Attached supplemental records for this well should show the details of ~ny rnul- tiple stage cer'nenting and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMAt~Y OF' VORMATION TESTS I NCI.UDIN(~ I NTEIZVAL T~S'~'EI'). PR~UEE'DA~A ~ '~COv~I~"OF OIL. GAS.- 35. G~GIC MARK~ ' WAT~ AND'MUD ., NA~ DST ~1. 993~'-993B'; I~P ~023, IFP 1B88, FFP 3623., FSIR ~3fi7, F~P ~96~ ~es~ed ~ox ~SO. Revexse c~xculo~ed 38 bbl$. o~ ~oLh~ mud cu~ a~l. Sog R~ver 97~' 882'3' 10% mud cuL, no woLe~, Shub]~k 9772' 88~6' DST ~2- 9860'-9890' ond 9910'-993~'; ls~ ~1o~ - I~P ~886, IFP 22~1, FFP 3189 Sodleroch~ 979~' 8862' FSIP ~363; ~nd Flow - IFP 22B2, 5FP ~228. Flowed 1008 B/D with 416 MCF/D of gas thru 24/64" surface choke and 5/8" bottom hole Base Zn 4 10054' 9079' choke. Oil gravity 24.7 and GOR 412. Base Zn 3 lOll5' 9129' Formation test reports attached ...... ,,, ,,,, , , 36. CORE DATA. A2~I'A('I{ ~RIEF DESCI{IPI'I~ON% OF IA~FIIOLC)(]Y. P(}F~OSITY, FRACWR~, APP~NT DIPS AND I)~'I'B2C'TEI) ~IIOWS OF' 011.. GAS o1{ Following are attached' (1) Conventional core description (2) Sidewall Sample Description WELL BISTORY KUPARUK 22-11-12 3-8-76 to 3-16-76: 3-16-76 to 3-29-76: Drilled 36" hole with rat hole machine to 53' from'matting board (71' from K.B.) Set 30", 156#/ft. LP conductor to 53' from matting board (71' from K.B.) Cemented to surface with 125 sx Permafrost cement. Spudded on March 8, 1976 at 9:30 a.m. Drilled 17½" hole to 750' ~(Mud: 10.3 ppg, 262 sec/qt, 10 cc). Reamed 17½" hole to 26" up to 750". Ran 735' of 20", 94#/ft., H-40, Buttress casing with guide shoe at 735', duplex collar at 689' and subsea hanger at 240'. Ran 4½" drill pipe and stabbed in 20" casing collar. Cemented with 4000 sx Permafrost cement. Released 20" casing after 12 hours. Nippled up 20" OCT head and tested to 400 psi. Nippled up 20" BOP stack and tested to 500 psi. Drilled casing collar,, cement and shoe. Drilled 12~"' hole 'to 994'.' Repaired~mud lines, pumps and desander. Continued drilling 12¼" hole to 2750'. Ran electric logs (DIL, Long Spaced sonic). Reamed 12¼" hole to 17½" to 2350'. Drill pipe backed off while opening hole. Attempted to screw in - pulls loose. Ran overshot - unable to make grapple grab. Redressed overshot with 6" grapples. Engaged fish at 570'. pulled out hole - recovered 1060' of 4½" drill pipe. Left in hole 12¼". bit, 17½" hole opener, 8" Monel drill collar, 9-8" steel'drill collars, 2- XO subs, 8 joints of heavy wall drill pipe, daily jars, and 4 joints of heavy wall drill pipe with top of fish at 1630'. Ran overshot and recovered remaining fish. Continued reaming hole from 12¼" to 17½" to 2750' (Mud: 10.2 ppg, 86 sec/qt, 10.5 cc). Ran 2723' of 13-3/8" , 72#/ft., N-80, Buttress casing with float shoe at 2723', duplex .collar at 2690', FO collar at 751' and OCT subsea hanger at 240'. Cemented through drill pipe with total 5000 sx Permafrost cement (slurry wt. 14.6 ppg). Lost returns when 4800 sx in; observed slight traces of cement with return. Nippled down BOP stack. Ran 2-3/8" tubing in 13-3/8" x 20" annulus to 240'. Cemented to surface with 150 sx Permafrost cement. 'Return good cement to surface. Installed 13-3/8" slip-on head and tested to 3000 psi. Nippled up 13-3/8" BOP assembly and tested to 5000 psi. Drilled duplex collar, cement and shoe. Well History Kuparuk 22-11-12 - cOntd, 3-29-76 to 3-30-76: Drilled 12¼" hole to 3000'. 3-30-76 to 4-5-76: Kicked off at 3000' with Dynadrill and drilled 8½" hole to 3137'._ Drilled 8½" hole with stiff hook-up from 3137' to 4104'. Drilled with Dynadrill to 4256'. Drilled with stiff hook-up from 4256' to 5674'. Drilled with Dynadrill to 5755', when drilling string stuck (Mud: 9.3 ppg, 37 sec/. qt. ,7cc. ). 4-5-76 to 4-8-76: Worked and jarred on stuck pipe. Spotted 20 gallons pipe lax and 1000 gallons diesel and worked pipe. Circulated out diesel oil. and rigged up Schlumberger and ran Dialog free point. Backed off at 4980' and pulled out hole with 140 joints drill pipe, 17 joints heavy wall drill pipe, daily jar. Fish left in hole consisted of bit, XO sub, Dynadrill, .bent sub, XO sub, 4 Monel drill collars, 5 steel drill collars, XO sub and. 16 joints of heavy wall d~ill pipe. Ran in hole with cut sub, bumper sub, oil jars and 8 6)~" drill collans. Circulated and screwed into fish at 4980'. Spotted 50 bbls diesel with 50 gallons pipe lax, and soaked for 6 hours. Jarred on fish. Rigged up Schlumberger, ran Dialog free point and backed off one sub above fish at 4979'. POH. Picked up 4½" DP and 13-3/8" DST tool. Ran with safety joint and screwed into fish at 4979'. Set packer at 2620', opened tool - approximately 20 minutes. Packer leaked. Tried to back off at safety joint at 4978', but backed off at above DST tool in Hydrospring. POH. Ran overshot, engaged fish, becked off at safety joint at 4978' and POH. 4-8-76 to 4-10-76: Spotted cement plug with 125 sx class G with 1½%, CFR-2 and 2%'CAC12 through open ended drill pipe at 4978'. Tagged cement stringers at 4433'. Drilled cement stringers and dressed off cement plug to 4831'. .4-10-76 to 5-2-76: Drilled with Dynadrill from 4831' to 4961' (Dynadrill attempted to stick). Drilled with stiff hook-up to 6373' Drilled with Dynadrill from 6373' to 6483'. Drilled wi~h stiff hook- up to 7069'. Drilled with Dynadrill from 7069' to 7298'. Drilled with stiff hook-up to 7350'. Drilled with Dynadrill and Sperry Sun steering tool from 7350' to 7538'. Drilled with stiff hook-up to 8570'. Drilled with Dynadrill and Sperry Sun steering tool from 8570 to 8672'. Drilled with stiff hook-up to 9082' Drilled with Dynadrill and Sperry Sun Steering tool from 9082' to 9084' in 1 hour, found Pyrite nodule in teeth. Drilled with normal' hook-up to 9973'. -3- Well History Kuparuk 22-11-12 - contd. 5-2-76 to 5-9-76: 5-9-76 to 5-10-76: 5-11-76 to 5-14-76: 5-14-~6 to 5-16-76: 5-16-76 to 5-18-76: Cored from 9773' to 10093' with 8-15/32" core head. Core #1: 9773-9821', cut 48' and recovered 42½'. Core #2: 9821-9827', jammed, cut 6' and recovered 4,. Core #3: 9827-9856', jammed, cut 29' and recovered 28~'. Core #4: 9856'-9916', cut 60' and recovered 58½'. Core #5: 9916-9972', cut 56' and recovered 55½'. Core #6' 9972-10017', cut 45' and recovered 44'. Core #7' 10017-10044', jammed, cut 27' and recovered 19½' Core #8: 10044-10093', cut 49' and recovered 47½:. Ran with 8½" bit. Ran Eastman Gyro through, drill pipe to 10040'. Drilled 8½" hole to 10200'. POH strapping drill pipe- corrected TD 10192'. Ran Schlumberger DIL -misrun,~reran DIL -misrun, GR-Sonic. Ran velocity survey. Schlumberger tagged TD 10168' to 10172'. 'Made a run with bit. and conditioned hole. Schlumberger ran Formation Density and Neutron Density log and Dipmeter. Tagged bottom at 10172' to 10175'. Made a run with bit and conditio'ned hole. Schlumberger ran 126 sidewall cores, left 22 bullets in hole. Made a run with bit and conditioned hole. Ran 7", 29#/ft., S-95, Buttress casing with BOT shoe at 10172', BOT catcher sub at 10128', BOT landing collar at 10115', HOWCO FO collars at 5749', 4051', 2925' & 2257', BOT 13-3/8" x 7" liner hangers #2 at 2075' & #1 at 2020' and BOT PBR at 2002'. Placed centralizers at +10170', 10125', lOllO' 10032' 9908' and 9867' 9733' and one joint above and below each FO. collar. Circulated .at 10172' for 3¼ hrs. Dropped ball'- set liner hange~r~s with~800 psi. Sheared ball.'~ ~,w.~, wi th 2000 psi. HOWCO cemented as follows' 20 bbl mud flush, 10 bbl water, 500 sx class G with 18% salt, 1% CFR-2 and 15% HR-7. First 300 sx had slurry weight 16 ppg and last 200 sx had 17 ppg. Latched plug in place with 2000. psi. Sheared PBR tie-back, spaced 1' off of seat, set slips, installed pack-off and tested to 5000 psi. Re-installed BOP and tested BOP assembly to 5000 psi and annular preventer to 2500 psi. Mud left behind 7" casing: 10.8 ppg, 43 sec/qt, 4.8 cc, ¼% sand and 17% solids. Picked up 3½" tubing and ran with 6" bit and 7" casing scraper, tagged bottom at 10110'. Circulated and POH. Strapped out and corrected PBTD 10106'. Well Hisl~ory Kuparuk 22-11-12 ' contd. -4- 5-18-76 to 5-19-76' 5-19-76 to 5-21-76-' 5-22-76 to 5-24-76: 5-24-76 to 5-25-76- 5-25-76 5-26-76 5-26-76 to 5-27-76: 5-27-76 to 5-28-76- 5-28-76 to 5-29-76- PKPaul/vm 6/7/76 Schlumberger ran GR-CL and perforated 9934-9935' with 4 JSF for WSO. Ran DST #1 HOWCO test tool on. 3½" tubing with 400 ' of water cushion, set packer at 9855'. Tested for WSO, recovered 38 bbl of frothy oil cut mud. Shake out 10% mud- no free water. Schlumberger perforated 9860-9890' and 9910-9935' with 4 JSF with 4" cased gun. Ran DST #2 HOWCO test tool on 3½" tubing with 4000' of water cushion, set packer at 9825'. Tested - flowed 1008 B/D of oil with 416 MCF/D of gas through 24/64" surface choke and 5/8" bottom hole choke (Oil gr. 24.7, GOR 412). Opened tool also for reduced flow for bottom hole sample collection. Ran 3½" tubing open ended to lOl06'. Conditioned hole to 10.6 ppg mud. Pulled to 9936'. Placed cement plug with 27 sx class G with 18% salt, 1% CFR-2 and 15% HR-7. Tagged plug top at 9810' POH - tubing collars dragged and hung with 20,000 ~ Pull, set 7" HOWCO EZ drill bridge plug at 8575'. Spotted 18 sx class' G cement, on top of plug. Tagged plug top at 8460'. Had considerable .problem with closing and opening of FO collars. Changed shifting tool and then it was OK. Cemented behind 7" casing through EO~_collar at 5749' with 227 sx class G (slurry wt. 16.2 ppg). Tested closed FO collar to 1000 psi - OK. Cemented behind 7" casing' through-~O__~ol~lar at 4051' with 218 sx Permafrost. Tested cloSed FO collar to 1000 psi - OK. Set. EZ drill'bridge plug on wi:re li'ne-'at,3420'. Laid cement,~':: ~. plug with 40 sx Permafrost. Tagged plug top at 3312'. Cemeni~d'behind 7" casing through _FO col. lar at 2925' with 260 sx Permafrost. Tested closed FO collar to 800 psi - OK. Set bridge plug on drill pipe at 2429'. Laid cement plug with 40 sx Permafrost. Tagged plug top at 2406'. Displaced the annulus 7" x 13-3/8" with 260 bbls .Arctic Pack (4% water at start, 4.5% at end) through FO co~!_!_.~_~_a.~t~._2257_' to surface. Tested closed FO collar to 1500 psi - OK. Displaced inside 7" casing from 2203' to surface with 120 bbls Arctic Pack of 10.4 ppg (6% water at start, 8% at end). Nippled down BOPs. Rigged down (Rig down started at midnight Installed OCT X-mas tree.. ,~i-i'~ KUPARUK 22-11-12 Core #1 9773''9821' Core~ #2 9821'-9827' Cut 48' Rec. 42.5'. 9773'-73.6 sand, qtz, vfg-silty, gry-brn, slightly calcareous, trace of glauconite,scattered dull gold fluor., poor yellow cut. 9773.6'-9782' sand as above with fair to good gold fluor, and good streaming cut. 9782'-88.5' sand as above with no fluor or cut. 9788.5'-9789' limestone, med. xln, gry-dark brn, very fossiliferous, gold fluor, with good.yellow to white cut fluor. 9789'-9790' limestone, vf xln, black with poor yellow fluor, and slight cut. 9790'-9793.7' limestone, m-crse xln, gry, fossiliferous, spotty yellow fluoresence and very poor to fair yellew cut. 9793.7'- 9799' limestone, vf-fxln, dark brn, very poor .yellow fluor and poor yellow-white cut fluor. 9799'-9800.5' limestone, vf xln, dark gry, 9800.5'-9803.5' shale, dark gry-brn 9803.5-9805.5'limestone, vf xln, gry-brn 9805.5-9807.7' shale, dark gry, slightly calcareous with a highly polished very slick surface on base of interval 9807.7'-9815.5' sand, quartz, vf med grained, brn, abundant tripolitic chert, pyritic, very bright gold fluor, streaming yellow-white cut fluor with crossbedding apparent. Cut 6' Rec. 4' 9821-9822' sand, quartz, fg, brn, abundant tripolitic chert, pyrite, trace of mica, good gold flour., good streaming yellow-white cut fluor. 9.8.22'-9823' sand, quartz, fg,.gry-brn, abundant tripglitic chert, poor spotty gold fluor., good gold Cut fluor. 9823'-9823.2' sand, quartz, fg, buff, with tripolitic chert, gold fluor, fractured. 9823.2'-9823.5 sand, quartz,· fg, tan with tripolitic chert, streaks of gold fluor, fair . to poor yellow-white streaming cut fluor. 9823.5'-9825 sand, quartz, f-mg, abundant chert, good gold fluor., & yellow-white streaming cut fluor., with occasional tight streaks and occasional streaks of white to gry claystone. 5/4/76 KUPARUK 22-11-12 Core a ' ' . . 9827' ' qtz ~3 9827 -9856 Cut 29' Rec 28.5' -9828.9 Sd, f-mg, gry-tan, Abdt Trip. Chert, gd go].d fluor. Yellow-white streaming cut fluor. 9828.9-9830.7 Sd as above interbedded w/gry Clyst. 9830.7- 9831.6 Sd as above. 9831.6-9831.7 gry Clyst. 9831.7-9833.6' Sd as above. 9833.6-9833.7' gry C!yst. 9833.7-9843.5' Sd as above. 9843.5-9843.8 gry Clyst. 9.843.8-9844.7' sd, qtz, fg, Lt gry w/Trip, chert, fair gold fluor. Poor-fair yellow- white cut fluor. 9844.7-9849.3' sd, qtz, f-mg, gry-tan, Abdt. Trip chert, good gold fluor., yellow-%~hite streaming cut fluor. Prominent fracture @ 9846.6 highly pyritized on fracture plane 9849.3-9849.7' gry silty Clyst. 9849.7- 9852.0 Sd as above, 9852.0-9852.4' gry Clyst, 9852.4-9853.6 sd as above, 9853.6-9854.3' gry Clyst, 9854.3-9855.5' sd as above. core %4 -9856'-9916' Cut 60' Rec. 58.5'. 9856-9858.3' (1) sd, qtz, f-mg brn, Abdt. Trip Chert, trace of pyrite and mica, good gold fluor, with yellow-white streaming cut fluor. 9858.3-9858.4 clay, gry soft abdt pyrite. 9858.4-9865' sd as above (1) with occ cly prtgs. 9865-9865.1' gry clay, 9865.1- 9867' sd, qtz, f-mg'brn, abdt Trip chert trace pyrite and mica abdt clay b~!ls and prtgs, mottled gold fluor., yellow-white cut fluor. 9867.'-9872' sd as above (!) , 9872-9872.3' gry Clyst. 9872.3- 9876.7' sd as above (1), 9876.7-9876.8' clay balls and prtgs. 9876.8-9879.3' sd as above (1). 9879.3-9881.7' sd, qtz m-cg, brn, abdt. Trip chert, good gold fluor. Yellow-white streaming cut fluor. 9881.7-9882.3' Lt gry Clyst. R882.3'-9887.2' sd as above (1). 9887.2'-9887.3' gry clay, 9887.3-9914.5' sd as above (1). 5/5/76 KUPARUK'22-11-12 Core # 5 9916'-9972' .Cut 56' Rec. 55.6' (1) 9916-9917.4' sd, qtz f-mg, brn Abdt TriP Chert, trace Mica. Good gold fluor., yellow-white streaming c6t. 9917.4-9919.6' sd, qtz vf-fg Buff-tan, trace Trip Chert, good gold fluor., yellow-white streaming cut. 9919.6-9919.7' sd, qtz, f-mg, Lt gry. 9919.7'-9921.7' sd, AA 9 9916' (1). 9921.7-9921.9' Lt gry Clyst w/mica. 9921.9- 9922.9' sd, qtz, f-cg buff-brn, Abdt Trip Chert and Mica. ~Black minerals? Well cemented. Spotty gold fluor., yellow-white streaming cut. 9922.9-9923.1' Lt gry, Clyst sdy w/Abdt Mica. 9923.1-9926.3' sd, qtz, m-cg, brn-dk brn~ Abdt Trip Chert, good gold fluor., yellow-white streaming cut. 9926.3-9926.5', it gr clay, 9926.5-9927.3' sd, AA (1) w/clay balls & prtgs. 9927.3-9932.0' sd, AA (1). 9932.0-9934.3' sd, qtz, fg gry. 9934.3-9939.3 sd AA (1). 9939.3- 9939.6' sd AA.(1) w/clay balls. 9939.6-9967.8' sd AA (1) w/few cly prtgs. & cly balls. 9967.8-9968.5' sd, qtz, m-cg gry w/gry clyst finely interbedded. 9968.5-9969.3' sd AA (1) · w/cly balls & prigs. 9969.3'9971.6' Sd AA (1) 5/6/76 Core #6 9972-10017' 45' .Rec.. 44'. 9972-9977.7' sd, qtz, fg-m, brn, Abdt Trip Chert, fair-good.gold fluor., Good streaming, yellow-white cut. 9977.7-9977.9' Clyst, gry. 9977.9-9984.0' sd, AA. 9984.0-9984.9' sd, ~ qtz, vfg, gry, well cemented. 9984.9-9986.3' ~ . sd, qtz, crs-very crs.,brn, Abdt Trip. Chert w/ Pyrite, gDod gold flour., gd streaming, gold- white cut. 9986.3-9989.2' sd, AA 9972. 9989.2-9992.2'- sd, qtz, fg, tan, Abdt. Trip Chert, good gold flour., yellow-white streaming cut. 9992.2-9995.3' sd, qtz,~ fg-med, gry, w/Abdt. Trip Chert, trace Mica,. no show. 9995.3'-10004.6' sd, AA 9972. 10,004.6-10,006.3' Clyst,gry. 10,006.3-10,016 sd, AA 9972 w/occ large Trip Chert & few clay balls, flour, weaker. 5/7/76 KUPARUK 22-11-12 Core' #7 10,017'-10,044' Core' ~.8. 10,044'-10,093' 5110176 Cut 27' Rec. 19.6'. 10,017-10,017.7' sd, qtz, f-mg, It gry-brn, abdt. Trip. Chert, tight- no Shows. 10,017.7~10,018.2' sd, qtz, f-mg, brn, abdt. Trip. Chert, poor gold flu°r., yellow-white streaming cut fluor. 10,018.2-10,020.1' sd, AA w/ccc, clay partings. 10,020.1'-10,020.3' gry c!yst. 10,020.3- 10,022.1 sd, qtz, f-mg, brn, Abdt. Trip. Chert, fair gol'd fluor.,yellow-white streaming cut fluor. 10,022.1-10,022.'6 sd, qtz, f-mg, it gry, very abdt. Trip. chert, no shows wet. 10,022.6'-10,022.7' sd, qtz, f-mg gry, Abdt. Trip. Chert, clay matrix, no shows. 10,02'2.7-10,023.5' Sd, qtz, fg, gry-brn, Abdt, Trip. Chert, no shows. 10,023.5- 10,023.7' sd, qtz, fg, gry w/interbedded claystone, no shows. 10,023.7-10,024.0' sd, qtz,. fg, gry, Abdt. Trip Chert, no shows, 10,024.0-10,024.5' clyst, gry. 10,024.5- 10,026.0' sd, as last described. 10,026.0 10,026.9 g.ry, clyst interbedded'w/sd AA.10,026.9- 10,034.0' sd, qtz, f-mg, brn, abdt. Trip Chert, ccc. pebbles, blk heavy oil specks - no ~luor, gd yellow str.eaming cut fluor from specks. 10,034.0-10,034.4' Cgl, gry-brn w/qtz, Trip. Chert, bik chert pebbles, no shows. 10,034.4-10,035.1' gry clyst. 10,035.1- 10,035.7' Cgl. as above.10,035.7'-10,035.9' gry clyst. 10,035.9-10,036.6' Cgl as above. Cut 49' Rec. 47.5'. 10,044.0-10,044.8' Cgl, pebble size, it gry, qtz, blk. Trip. Chert. · Tr. pyr. & mica, poorly sorted~ no shows. 10,044.8'-10,048.0' sd, qtz, vf-fg, buff, abdt. Trip. chert, tight, no shows. 10,048.0- .10,050.7' sd, qtz, f-mg,· It gry, Abdt. Trip. chert., finely disseminated pyrite, tight, clay prtgs. @ 10,050.7'. 10,050.7-10,054.3' sd, qtz, .mg, it gry, abdt. Trip chert. 10,054.3'-10,056.8' sd, qtz, vf-fg, buff abdt. Trip. chert. 10,056.8-10,061.7' sd, qtz, f-mg, it gry, w/scatter'ed trip. chert · and blk chert, poorly sorted. 10,061.7- 10,064.5' Pbl cgl, gry-blk, tight, qtz, blk chert, pyrite..10,064.5-10,079.0' sd, qtz, ~m-cg, gry w/trip., chert (2) 2-3 inch intervals of pebble cgl @10,066' and 10,071'. 10,079.0'-10,091.5' Pbl cgl, some 50 mm cobbles, gry, w/trip 'chert,' qtz~,'?.......b~!'.ch.'e~i~ ~i~h'.ty pyritic. Formation Testing Service Report HAlllIIIlllTITIV SEIt III~, E$ DUNCAN, OKLAHOMA TIME or~zon ~ne to 1000 p.s.i. FLUID ] ~cket Dote 12-18-76 N~,=U~r 607319 Kind Halliburton NORTH SLOPE of Job HOOK WALL District Te~ter MR. PHiLLiPS V¥itness HR. MEYER DrU!mg PARKER DRILLING COMPANY BC S Contractor EQUIPMENT & HOLE DATA Formation Tested Sadl eroche". Elevation 64 ' Net Productive Interval Perfo~atff OhS 95 ' All Depths M~sured From Total Depth Sampler Pressure Recovery: Cu. Ft. Gas cc. Oil cc. Water cc. Mud Tot. Liquid cc. Gravity Gas/Oil Ratio DATA Recovery Water Recovery Mud Recovery Mud Filtrate Mud Pit Sample Mud Pit Sample Filtrate .P.S.I.G. at Surface SAMPLE ° APl @ °F. RESISTiViTY cu. ft./bbl. CHLORIDE CONTENT __Kel 1S Bushing 10109' Main Hole/Casing Size 7" Drill Coilar Length I.D. Drill Pipe Length 9788' I.D. Packer Depth(s) 9825 ' °F. ppm °F. ppm °F. ppm °F. pprn °F. ppm Mud Weight 10.6 vis 43 Sec. ~,~: D..e, pth Taster Valve 9807' 24-8-7 2.992" TYPE AMOUNT Depth Back Surface 16- Bottom Cush~on Fresh water 4000' Ft. Pres. Valve Choke 64" Choke .62" Recovered Feetof Well flowed oil Recovered Feet of Recovered Feet of Recovered Feet of Recovered Feet of Remarks SEE PRODUCTION TEST DATA SHEET. Ft'- I Ft. .~ Ft. lB: >?' CTE TEMPERATURE Est. °F. 9847' Actual 222 'F. ,nitial Hydrostatic Initial ~.~ Flow Final = Chart time exDined Gauge No. 3647 ' Gauge No. Depth: 9812I ' Ft, Depth: 4~ Hour Clock ' Initial c o Flow ~ 8'c Final Closed in 3646 9817' Gauge No. 3637 Depth: 9842' Ft. Ft. 48 Hour Clock 48 Hour Clock. Blanked Off NO Blanked Off No Blanked Off Yes Field 4882 Pressures Office 4921 Pressures Field 4886 Office 4942 2217 Pressures Field 4909 Office 4917 TIME Tool 5-1 9-76 A.M. O?e,~d 0602 P.M. Opened 0005 A.M. Bypass 5- 21 P.M. Reported Minutes Computed Minutes 2220 2241 2260 2299 2304 31 79 31 84 31 89 3187 3191 3200 820 822 Oosed in 4361 4363 4363 4367 4358 4360 1223 1221 2205 - Initial ~.g_ Flow ~. Final 2206 2252 2254 2356 4234 4236-CTE 4228 4230-CTE - 4227-CTE 725 CTE Closed in Final Hydrostatic - 'CTE - CTE - CTE A-FA o o o t o1~1~1 ItlI-~ll---PI~INTED IN U.~,,A. t. ITT: L~'5 9~67t h)M U/74 FLUID Sampler Pressure Recovery: Cu. Ft. Gas cc. Oil cc. Water cc. Mud Tot. Liquid cc. Gravity :-Gas/Oil Ratio SAMPLE DATA .P.S.I.G. at Surface APl @ °F. cu. ft./bbl. . ~cket Date 12-18-76 Number 607819 Kind Halliburton of Job HOOK I/JALL District NORTH SLOPE Tester MR. PHILLIPS Witness FR. MEYER Drilling : Contractor PARKER DRILLING COMPANY SC S EQU I PMENT & HOLE DATA Formation Tested Elevation Ft. Net Productive Interval Ft. All Depths Measured From Total Depth Ft. RESISTIVITY CHLORIDE CONTENT Recovery Water @ °F. ppm Recovery Mud @ °F. ppm Recovery Mud Filtrate @ °F. ppm Mud Pit Sample @ °F. ppm Mud Pit Sample Filtrate @ °F. ppm Mud Weight vis cp Maln Hole/Casing Size Drill Collar Length Drill Pipe Length Packer Depth(s) Depth Testa,- Valve I.D. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke Choke Recovered Feet of Recovered Feet of Recovered Feet of Recovered Feet of Recovered '. Feet of Remarks FOURTH GAUGE' Ft, TEMPERATURE ,, Est. °F. Gauge No. 3636 Depth: 9846' Ft. 48 Hour Clock Blanked Off YeS Gauge No. I Gauge No. Depth:, Ft.[ Depth: .Hour Clock t Blanked Off BlankcJ Off Ft. Hour Clock Tool Opened Opened TIME Actual °F. Field -- ,nitial Hydrostatic 4887 Initial 2325 l~'~Fl°w_ Final 3224 Closed in 4379 '~'o Initial 2379 8'c Flow ~ ~,. ~nal 4271 Closed in Initial _~._o Flow--__ ,c ~- Final Closed in Final Hydrostatic CTE -- Chart time FO~W IIiI-RI--P~IINTED IN U.II.A. Pressures Office Field 4863 2712 3218 4377 2375 4260-CTE CTE Office Field Pressuras 2xpired Pr( ssures . Office Bypass Reported Minutes FORMATION T S" DATA A.M. P.M. A,M. Computed Minutes l-ITi',.e;'~ 2¢t,-I lO~,1 0/14 1 9860 '-9935' .62" +20 60781 9 Casing perfs. Bottom choke Surf. temp °F Ticket No ..... Gas gravity , OiFgravity, C_fOR Spec. gravity. .Chlorides ,opm Page l INDICATE TYPE AND. SIZE OF GAS MEASURING DEVICE USED D~te 5L 1 9- 76 Choke Surface Gas t L/quid Time a.m. Size Pressure Rate! Rate Remark,~ p.m. psi MCF BPD / j Se~ packer ca 9825' 2:01 2:02 Tool ooened with a fair blow 2:20 16/64" 9 " 70 I Fluid to surface -- cushicn 2'47 3'05 " 230 ,,, 3: 15 " 275 ....... 3:30 " 450 -- . 3:47 24764' 520 j Changed choke 3'50 ,, I 485 Gas to surface 3'53 " 500 Rat hole mud to surface 4'15 " 550' i Oil cut mud to surface ....... 4'30 " 650 4'45 " 675 Good oil to surface , , 5'00 " 650 Pressure Stable Ca 650 PSI ,. 6'30 " 650' " ' 7'00 " 660 Pressure stable 0 660 PSI 11 '00 ,, 660 ,, 12'00 PM " 650 Pressure stable 0 650 PSI 2'18 " 650 , Started closing tool, very muCh torque . , in 3~" tubing I 3'42 Closed tool 5---20---76 ....... 12'00 Opened tool with a fair blow ., 12'15 Close( 75 ' 12:18 8/64 150 Opened to pit ., FOR/4 IIi,Z-FI --PR NTE:D IN U.S.A. PRODUCTION TEST DATA. LITTLE'S 9657-:' !I,~1 8/74 ,, , C07819 Casing perf$, Bottom choke ,.,Surf. temp °F Ticket No. Gas grovity. Oil gravity, GOR ,. Spec. gravity. .Chlorides_ ppm Res. @ °F Page 2 INDICATE TYPE AND SIZE OF GAS M[ASURING DEVICE USED Date J Choke Surface : Gas Liquid Time a.m.[ Si'ze Pressure Rate Rate Remarks psi MCF BPD p.m. .......... 12' 35 8/64" 800 t Oil to surface 1'35 6/64" 1200 1 ....... Changed choke 2'00 " 1250 .... II 2.30 1 300 2'49 7/64"1 Changed choke 1325 3:00 1350 1275 4:30 1 260 4:45 1160 ,,, 5: O0 " 1 200 5'15 1160 5' 30 11 75 , , 6 '00 " 1 200 6'30 1225 1250 II 8:00 1275 9' 30 1 260 1 2- O0 " 1 260 II 00'05 Rotated tool closed, in reverse positic l'O0 Reversed out 1'25 Pulled packer loose, started out of hal PRODUCTION TEST DATA LIT'FLk"5 9C612 ~,~4 13/74 , Ticket - 607819 Gauge No. 364~ Depth 9812 Clock No. 10051 48 hour No. First First Second Second Third Third Flow Period Closed In Pressure Flow Period Closed In Pressure Flow Period Closed In Pressure Time Deft. ..PSIG Time Dell. ] ~.A_ t Jr- ~} ..PSIG Time Dell. ~_PSIG Time Dell .A_ t mL (~ ~.PS1G Time Dell. ~PSIG Time Deft. J ,.,AO,, /emp ...... / bug letup ..... , /emp .... , bug-- letup .... ,, letup. 0^,~,~ Temp. .uu Corr. .ug,U J i~ Corrt .u. ou Corr. .O00' e Corr. .uug Corr. .uu g~ Corr. oJ .b--~-O 22-~-- -~-O-~j 318-~- --~-0-0-~ 2~-~- .... ~ ~ ~ 21 (.~--~'375~i W27-~--~-]~ ~266 .0703 4019 ~ .5-0-~'~ .... ~26~~-:-6'78~-] ..... ~'~2'~- ~2'i'08---423g- -~ · l~Z~'-~"32]~IJ-i-:2'2~-J--. ........4349-.}[ .4216] 4239 ]J ........ ~ .................................... 7 ........ ~ ~ .................. · ............ - ~ -- ]~t 1.2527 3195 1.4923j 4050 il. J --~II;.7-~"--'~]ZJ~ ..... ' ~ i~ ~fJ~ ~-4~ -i ~'~'~-J - '-4'$'~- ......a~-~m~"FHF"~-~ (iRED AFTER ,Gquge lqo. 3646 0]~ .--- :--' 0000 2260 ..... 000_0_. -l~h. --12 5-bi- -:~-7-3 7 .1 359_ 3l .2518 3374 .4078 si .5036 3266 .6796 ~o~ t 13,9 3s06 __,~_!__,2 5.?_] 132 e~ ___JN ,.4g 5 2_ ~2113:~.o800 3187' !11.76~0 Read,hq Inter.ol 75 il 81 REMARKS: *Interval = 72 minutes **Interval = 87 minutes Depth 9817 3187 .0000 2254 _~218 .... C ._.~263____.0705 4023 __43!_8 T-2T'i~-F-42-40 .... _4342 .3524 4219 4_3_4] .4229 4240 __4351_._ .4900 4230**~ _4356__ _~3_~8 [I CHART ilME EXP] 4361 APPROXIMATELY _43_6_3 .... ! ~367,* 42 Clock No. 9299 4[, hour k ~2 M'I'NUTE$ .... Minutes ***interval = 53 m~nutes ****interval = 40 m~nutes C - Choke change ~o .... ,.,,,_,.,, ............ SPECIAL PRESSURE DATA Gauge No. First Flow Period Time Deft. J PSIG Temp. .000" 'Corr. .0000 2304 · 1 2_82_. 37_45' .2564 .3846 .5128 .6410 .7691 .8973 1.0255 1.1537 1.2819 1.4050 3388 3309 3279 3267 3252 3241 '3228 3219 3207 3200* 3637 't Depth First Closed In Pressure Time Deft. .000" PSIG Temp. Corr. .0000 1389 ,2777 .4166 _. .5554 _ .6943 .8331 .9720 1 .ll08 1.2497 1.3885 1.5274 1.6662 1.8051 1.9439 2.0930 9842' I Clock No. Second Flow Period , 9293 Second Closed In Pressure Time Deft. PSIG Time Deft. .000" Temp. Corr. .000" 3200 .0000 2356 _ 4218 .0510 4263 .0719 4009 4287 .1438 4128 4304 (.1640 4315 .2157 4232 4324 .2790 4330 .2876 4254 4336 '3930 4227***~ 4343 4346 CHART T [ME FXPI E~ ){-F-~EI 4349 APPROXI Y _2 l0 MIii-[]'T 4353 4355 4358 4360** t+~ log---F- PS IG Temp. Corr. 48 hourI Ticket No. Third Flow Period Time Deft. .000" PSIG Temp. Corr. ' 607819 Third C!osed In Pressure Time Deft. Lo- t Jr' t~ .000" g---~ PSIG Temp. Corr. , Gaug,e No. 3636 · 0000i 2712 .0000 .1 276','-3-~-f~j- --~--1- (.1 67~ 3781_)C .25511 3090 -_~_1_4."]_;-36-' .382-7] 3328 .5514 5i .5102', 3300 .6893 __~ ~.3} ~g 3~ ] s* ~1"6~.42- ~ ~----- t i12 0780 REMARKS: Depth 9846' Clock No. 81 *Interval = 7_2_ m,__izn_u_t ~ _. 7578 48 hour _32__!_8___ ____._0.0 O_ 0 2375 4238 (.05] 0.3_7.A.3_)__C___ _4 2.~.2 ............. 1-6; f-~__5....;3 ~ ~__. 4306 .1429 4145 _4322 __(_._] 62_Q._~]__56~C__. J-3..,5_ ......... 4344 ( · 2_~ 80___4_27] }_C_ 4350____.2858 4271 4357 · 3 ~_7_3._ ._4_233 4361 .4287 4253 4364 .5002 4245 t 4370 Ii --~-7 ~-0---42-60'** ~ .43_7_5 ___jI-~-PPRO~IICA: ELY _3~8 MINU_T! ........... I ..... !', ..... 1 .... ~2 h **In.terv~Ll__~ 87 mJJ~utes _*_**Im~terval = _6_2 miJ3utes ****Interval__--_ 44 minutes C = Choke change Minutes t FO.RNI I$3-R~---PRINTED IN SPECIAL PRESSURE DATA ~-- ;'~:: ...... ~, ":"~ ~--"'~-'~ ~r' ~ i':' ~' ;]~ ~ LITTI..E'g 9667~ 75C 8/74 . ~ TICKET NO. 607819 O.D. DHII Pipe or Tubing ................ Reversing Sub ....................... Water Cushion Valve .......... : ..... Drill Pipe ......................... 3~" Drill Collars ...................... Handling Sub & Choke Assembly ...... 3½" Dual CIP Valve ................... Dual CIP Sampler ................... 5" Hydro-Spring Tester ................ 3 7/8" 1,75" 2.992" Multiple ClP Sampler ............... Extension Joint AP R-nning Case ....... (.2) 3 7/8" ,, I .25" .75" 2.55" Hydraulic Jar .................... 3 7/'8" VR Safety Joint ............... Pressure Equalizing Crossover ......... Packer Assembly ..... .RT!S ......... 3 7/8" 5 3/4" Distributor Packer Assembly ................... Flush Joint Anchor ................. Pressure Equalizing Tube ' Blanked-Off B.T. Running Case ....... Drill Collars ...................... Anchor Pipe Safety Joint ............ Packer Assembly ................... Distributor ........................ Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor Drill Collars ...................... Flush Joint Anchor Blanked-Off B.T. Running Case .... ( 2)'. Total Depth ....................... 2 7/8" 2.441" 3 7/8" 3" HT-500 Temp. Recorder LENGTH DEPTH .97' 9788' 6.23' 9807' 4.92' 5.02' 2.53' 3.97' 9812' 9817' 9S25' 9.72' 4.05' !' 9842' 9846' 98A7' !0109' NOMENCLATURE b -- Approximate Radius of Investigation ........................ Feet b, -- Approximate Radius of Investigation (Net Pay Zone h~) ......... Feet D.R.-- Damage Ratio ......................................... El -- Elevation .............................................. Feet GD --_ B.T. Gauge Depth (From Surface Reference) ................... Feet h -- Interval Tested ...................................... Feet hi --- Net Pay Thickness ....................................... Feet K -- Permeability ........ ~ ................................ md K~ '-- Permeability (From Net Pay Zone h~) ........................ md m -- Slope Extrapolated Pressure Plot (Psi¥cycle Gas) .............. psi/cycle OF ~ -- Maximum Indicated Flow Rate ............................ MCF/D OF2 ~--~ Minimum Indicated Flow Rate ............................ MCF/D OF3 -- Theoretical Open Flow Potential with/Damage Removed Max ..... MCF/D OF4 ~--- Theoretical Open Flow Potential with/Damage Removed Min ..... MCF/D -- Extrapolated Static Pressure .............................. Psig. -- Final Flow Pressure ...................................... Psig. -- Potentiometric Surface (Fresh Water *) ...................... Feet ~--- Average Adjusted Production Rate During Test ................ bbls/doy -- Theoretical Production w/Damage Removed .................. bbls/day --Measured Gas Production Rate ............................ MCF/D -- Corrected Recovery ..................................... bbls -- Radius of Well Bore ..................................... Feet -- Flow Time ........................................... Minutes "-- Total Flow Time ......................................... Minutes ~ Temperature Rankine .................................... °R -~ Compressibility Factor .................................... '~ Viscosity Gas or Liquid ............................... CP Log -- Common Log *'Potent[ome+ric Surface Refere,~ce to Ro~'ary Table When Elevation Not Given, Fresh Woter Corrected to I00 F. Ps Q Q~ R t to T Z FOrmation Testing Service Report DWISION OF OI!. ,'.:..;D AIqCN ,(3, ~" .: "- ": Each Horizontal Line Equal to 1000 p.s.i. T~cket FLUID SAMPLE DATA Date 5-1 7-76 ,~mber 608206 '?{ Sampler Pressure .P.S.I.G. at Surface Kind WATER SHUT OFF liburton Recovery: Cu. Ft. Ks of Job H00K WALL ~rict NORTH SLOPE cc. Oil cc. Water Tester MR. PHILLIPS Witness MR. MEYER cc. Mud Drilling ' Tot. Liquid cc. Contractor PARKER DRILLING COMPANY DR S Gravity 23 ° APl @ 60 °F. EQU I PM E N T & H aL E DATA Gas/Oil Ratio cu. ft./bbl. Formation Tested Sadlerochet RESISTIVITY CHLORIDE Elevation 64 ~ Ft. CONTENT Net Productive Interval 1" Ft. Recove}y Water @__ °F. ppm All Depths Measured From Kelly Bus hi ng Recovery Mud @ °F. ppm Total Depth 10109 ~ Ft. Recovery Mud Filtrate @ °F. ppm Main Hole/Casing Size 7" Mud Pit Sample @ °F. ppm Drill Collar Length - I.D. - Mud Pit Sample Filtrate @ °F. ppm Drill Pipe Length 9818' I.D. 2.992" Packer Depth(s) 9855 ~ Ft, Mud Weight 1 0.6 vis 43 .sec x~: Depth Tester Valve 9836 ' Ft. TYPE AMOUNT Depth Back Surface Bubble Bottom Cush~on 4000' Fresh water Ft. Pres. Valve Choke hose Choke ,62" Recovered 4380 Feetof frothy oil · Recovered Feet of Recovered Feet of ~ 0 Recovered Feet of Recovered ,- Feet of Remarks SEE PRODUCTION TEST DATA SHEET Gauge No. 3647 Gauge No. 3646 Gauge No. 3637 o TEMPERATURE TIME Depth: 9842 Ft. Depth: 9847 Ft. Depth: 9873 Ft. -r- - 24 Hour Clock 24 Hour Clock 24 Hour Clock i Tool A.M. Est. °F. Blanked Off No Blanked OffiCio Blanked Off Yes Opened 00' l 0 P.M. r- , ' 998 i ' Opened A.M. · Actual 2~ °F. Pressures Pressures Pressures Bypass 0~' ~0 P.M. Field Office Field Office Field Office Rep0rte'd Computed Initial Hydrostatic 5023 5002 5023 4995 5040 5017 Minutes Minutes I..~° Initial 1569 832 11588 1080 1605 1103 ~'r_ Flow -- ~ F~.ol 3624 3623 3623 3626 3633 3634 140 129 Closed in 4375 4379 4367 4367 4374 4381 60 71 ~ Initial __ ~.~ FlowFinal Closed in / Initial ~ .~_.9 Flow ~:, ~. Final Closed in ' Finol Hydrostotic 4936 4940 4937 4939 4964 4964 lei-Et--PRINTED IN U.$,A, FORMATION TEST DATA Ticket , FLUID SAMPLE DATA Date 5-17-76 Number 608206 -.,,- -Sampler Pressure .P.S.I.G. at Surface Kind WATER SHUT OFF Halliburton Recovery: Cu. Ft. C~s of Job HOOK WALL,District NORTH SLOPE cc. Oil · cc. Water Tester MR. PHILLIPS Witness ~R, 'cc. Mud Drilling : Tot. Liquid cc. Contractor PARKER DRILLING COMPANY Gravity ° APl @ °F. EQ U I PM E N T & H O L E DATA Gas/Oil Ratio cu. ft./bbl. Formation Tested RESISTIVITY CHLORIDE Elevation Ft. CONTENT Net Productive Interval Ft. Recove;y Water @ °F. ppm All Depths Measured From Recovery Mud @ °F. ppm Total Depth Ft. Recovery Mud Filtrate @ °F. ppm Main Hole/Casing Size Mud Pit Sample @ °F. ppm Drill Collar Length I.D. Mud Pit Sample Filtrate @ . °F, ppm Drill Pipe Length I.D. Packer Depth(s) Ft, Mud Weight vis cp Depth Tester Valve Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke Choke ,.. Recovered Feet of ~ Recovered Feet of Feet of Recovered Recovered Feet of o_ O Recovered Feet of Remarks FOURTH Gauge No. 3636 Gauge No, Gauge No. ::3: TEMPERATURE TIME Depth: 9877 Ft. Depth: Ft. Depth: Ft. r-' 24 Hour Clock Hour Clock Hour Clock Tool A.M. O .... Est. °F. Blanked Off Yes Blanked Off Blanked Off Opened P.M. m Opened A.M. Actual °F. Pressures Pressures Pressures Bypass P.M. Field Office Field Office Field Office Reported Computed i Initial Hydrostatic 5048 5060 Minutes Minutes , Initial ] 603 111 5 ~'c Flow ,rE Final 3647 3650 Closed in 4390 4403 ~ Initial c o Flow uTM Final Closed in Initial ~ Flow, ~_~. Final Closed in _ Final Hydrostatic 4958 4971 I~'OR~ 181-RI---PRINTE:O IN U.S.A. FORMATION TEST DATA .,-r-,,.., ,,,,,,, ,o, ,,/,, /4"" Casing perfs. 9934-9935' 62" 608206 Bottom choke · Surf. temp,. +20 .°F Ticket No. . Gas gravity , ., Oil gravity, GOR Spec. gravity. ,Chlorides ppm Res. INDICATE TYPE AND SIZE OF GAS MEASURING DEVICE USED .... iD ate J Choke Surface Gas Liquid Time a.m.I Size Pressure Rate Rate Remarks p.m. psi MCF BPD 3ubble 12'10 AM hose Opened tool with a very weak blow · 1~'15 " Fair blow _. 1' 15 " 15 2: 00 20 2'30 . 300 Closed tool to reverse position and reverse out. 3'30 Pull packer loose 4'20 Started out of hole. ll'00 Tools laid down. ,,, ......... ,_,.,, .... ,,u...,,. PRODUCTION TEST DATA LITTLE', ( 1 10 11 12 13 14 -- 15 ,Gouge No. 3647 First Flow Period J'Depth 9842' First Second Flow Period Clock No. 10051 Second Closed In Pressure Ticket ~4 hour No. Third Flow Period 608206 Third Closed In Pressure Closed In Pressure Time Deft. PSIG Time Deft. _~ PSIG Time Defl. PSIG Time Defl. .~ P$1G Time Defl. PSIG Time Defl. Lo_t -~- ~ PS IG Temp. Log Temp. Temp. Log Temp. Temp. Temp. .000" Corr. .000" Corr. ,000' Corr, .000" Corr. ,000" Corr. .000" Y T Corr. .000 832 .000 3623 · 1007 1984* . 0207 4322** .1702 2294 .0379 4326 · 2396 2643 .0552 4340 · 3091 2941 .0725 4347 .3786 3207 .0897 4352 .4480 3623 .1070 4357 · 1 242 4364 .1415 4366 -- .1 587 4368 ,. 1760 4370 .1932 4373 .2105 4375 .2277 4377 .2450 4379 ;auge No. 3646 Depth 98z .000 .0973 .1645 1 O80 8 9 10 11 12 13 1986' · 000 .0202 3626 4311'* 2287 .0370 4316 .2316 2633 .0539 4326 .2987 2930 .0707 4335 .3659 3197 .0875 4340 .4330 3626 .1043 4346 .1212 4351 · 1380 4354 14 Reading Interval REMARKS: 2O .1548 4356 .1717 4360 .1885 4363 .2053 4365 .2222 4367 .2390 4367 7' Clock No., 9299 hour 24 5 Minutes *-29 mi nutes **-6 mi nutes. ,o..,._.,-..,.T.o,....... SPECIAL PRESSURE DATA Ceuge No. 12 13 14 First Flow Period Time Deft. .000" · 000 3637 PSIG Temp. Corr. 1103 J Depth First Closed In Pressure Time Defl. .000" · 000 L t-t-8 og--~-- PSIG Temp. Corr. 3634 · 0973 2007* . 0207 4294** .1645 2311 .0380 4327 .2316 2653 .0552 4343 .2988 2945 .0725 4349 3209 · 0897 .1070 .1243 .1415 · 1588 .1760 .1933 4358 · 3659 .4330 3634 4363 4365 4370 4372 4376 4377 9873' Second FIo~ Period Time Deft. .000" PSIG Temp. Corr. Clock No. 9293 Second Closed In Pressure Time Deft. .000" .2106 4379 .2278 4381 .2450 4381 ,o0Z_ PSIG Temp. Corr. JTicket 24 hour No. Third Flow Period Time Deft. .000" PSIG Temp. Corr. 608206 Third Closed In Pressure Time Deft. Log .L~__~ .000" PSIG Temp. Corr. ;auge No. 3636 Depth 9877' Clock No. 6307 hour 24 · 000 1115 .000 3650 · 0976 2083* .0203 4339** .1648 2419 .0372 4353 .2321 2690 .0541 4357 .2994 .3667 2985 3247 .0710 5 12 ,]3[ 151 .0879 4374 4381 4340 3650 . 1048 4385 .1217 4388 · 1 386 .1555 .1724 .1893 .2062 .2231 4392 4394 4396 4397 4399 4403 4---4-03 ,Readin9 Interval 20 5 Minutes REMARKS: *-29 minutes **-6 minutes. FORM 1a3-RI--PRINTE:D IN U.S.A. SPECIAL PRESSURE DATA TICKET NO. 608206 Drill Pipe. or Tubing ................ Reversing Sub ...................... Water Cushion Valve ................ Drill Pipe ........................ Drill Collars ...................... Handling Sub & Choke Assembly ...... Dual CIP Valve ................... Dual CIP Sampler .................. Hydro-Spring Tester ................ O. Do 3½I' Multiple ClP Sampler ........ - ....... Extension Joint .................... 2 7/8" 3½" 11 3 7/8" AP Running Case ............ .(2.).. 3 7/8" Hydraulic Jar .................... . VR Safety Joint .... ................. Pressure Equalizing Crossover ......... Packer Assembly ..... .RTT. S. ......... 3 7/8" 3 7/8" 5 3/4" Distributor ........................ Packer Assembly ................... Flush Joint Anchor ................. Pressure Equalizing Tube ........... Blanked-Off B.T. Running Case ....... Drill Collars ...................... Anchor Pipe Safety Joint ............ Packer Assembly ................... Distributor ........................ Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars ...................... / Flush Joint Anchor .................. Blanked-Off B.T. Running Case . (2)... Total Depth ....................... 2 7/8" 3 7/8" HT-500 Temp. 2.992" .5II .87" .62' 3.00" 1.25" .75" 2.55" 2. 441" 3.00" recorder LENGTH DEPTH .97' 9818' 4.56, 6.74' 6.23' 9836' 4.92' 5.02' 2.53' 3.97' 9842' 9847' 9855' 9.72' 4.05' 1' 9873' 9877' 9981' 10,109' NOMENCLATURE b - Approximate Radius of Investigation ........................ Feet b l -- Approximate Radius of Investigation (Net Pay Zone h~) ...... Feet D.R.-- Damage Ratio ........................................... El - Elevation .............................................. Feet GD -- B.T. Gauge Depth (From Surface Reference) ................... Feet h -- Interval Tested ......................................... Feet hi m Net Pay Thickness ...................................... Feet K -- Permeability .......................................... md K~ -- Permeability (From Net Pay Zone h~) ........................ md m -- Slope Extrapolated Pressure Plot (Psi2/cycle Gas) .............. psi/cycle OF~- Maximum Indicated Flow Rate ............................ MCF/D OF: m Minimum Indicated Flow Rate ............................ MCF/D OF3 -- Theoretical Open Flow Potential with/Damage Removed Max ..... MCF/D OF4 ~ Theoretical Open Flow Potential with/Damage Removed Min ..... MCF/D P s ~ Extrapolated Static Pressure ............................... Psig. P F -- Final Flow Pressure ...................................... Psig. Pot -- Potentiometric Surface (Fresh Water*) ...................... Feet Q - Average Adjusted Production Rate During Test ................ bbls/day Q~ - Theoretical Production w/Damage Removed .................. bbls/day Q g -Measured Gas Production Rate ............................ MCF/D R - Corrected Recovery ...................................... bbls r ~, -- Radius of Well Bore ...................................... Feet t - Flow Time ........................................... Minutes t o : Total Flow Time ........................................ Minutes T - Temperature Rankine ................................... °R Z -- Compressibility Factor .................................. ~j -- Viscosity Gas or Liquid .............................. CP Log -- Common Log * Potentiometric Surface Re{e,ence to Ro~ary Table When Elevat.~n N~t Given, Fresh Water Corrected to !00 F. CORE LABORATORIES, INC. BALLASt TEXAS 75247 June 1, 1976 Mobil Oil Corporation P. O. Box 5444 Denver, Colorado .Attention: Mr. Dick Wood Subject: Core-Analysis Data Kuparuk 22-11-12 Well Wildcat Field North Slope, Alaska Gentlemen: Diamond core equipment and water base drilling Fluid were used in extracting core From the subiect well. These cores were pre- served in plastic and submitted po our Anchorage laboratory For permeability, pore;ify, grain density, and Fluid saturation deter- minations. The results of these analyses are presented in the accompanying report. We sincerely appreciate this opportunity to serve you and trust we will be called on again in the Future. Very truly yours¢ CORE LABORATORIES, INC. James A. Cusator District Manager JAC:sme UN TED $ T A T I: .~ CANADA .~ O U T H AMERICA EUROPE AJ" RICA A U .% T F~ A L I AA ,.~ I A Company MOBIL OIL CORP. We. KUPARUK 22-1]-12 l:ie~d WILD CAT County NORTH SI,OPE State l.ocation CORE 1.A13OI/ATOI{IES, INC. .Pctrole. m R escrw, ir En.gi,~ccri,,14 DALLAS, TEXAS For ma t ion C,>re.~ DIAMOND Drilling Fluid hT,h.qKa , Elevation~ CORE ANALYSIS RESULTS (Figures in parentheses refer to footnote remarks) PERM EA BI LITY R ES1D U A L MILLIDARCYS SATURATION SAMPLE DEPTH ] I POROSITY GRAIN I -- F. EMARKS NUMBER FEET Horizontal Horizontal PERCENT DENSITY Oil Total Water Maximum 90° Vertical % Pore __ % P__ore ....... 1 2 3 5 6 7 18' 9: 10 13 15" Z6 18 19 2O 22 23 24 25 9773 977/4 9775- 9776 9777 9778 9779 97' 0 9781 9782 9783 9784 9785 9786 9787 979o 9791 9792 9793 9794 9795 9796 · 9797 9798 ~.o 6.0 17.3 2.69 lo.4 4.6.7 3.4 '3.2 i7.0 2.69 17.8 ~4.2 2.5 2.5 16.o 2.71 17.5 46.8 1.8 '~1.3 12.8 2.71 19.6 40.4 .. 2.5 1.9 i5.3 2.68 22.0 /43.6 1./4 2.5 14.0 2.70 13.7 51.2 1.6 2.2 15.1 2.70 17.4 50.9 :_1.8 2.~ i5.7 2.67 12.3 52.8 1.3' 1.3 14.9 2.69 13.o 55.3 0.4 0.3 11.3 2.75 10.6 63.7 0.2 0.2 7.7 2.77 ~9.3 49.6 0.4 0.2 4.9 2.82 28.6 44.9 0.2 0.3 6.4 2.79 4.7. 59.8 0.4 0,8 11.4 2,72 1.5 67.3 0.6 1.9 .11.9 2.70 9.7 65.1 o.1 2.7 2.70 38.1 51.o o.1 4.0 2.75 31.9 0.2 3.0 2.71 26.7 60.0 o.1 1.8 2.75 18.3 48.4 o.1 2.1 2.76 27.1 38.5 0.2 t.3 2.73 22.7 54.2 o.o o. 5 2.68 8.3 75.0 0.1 1.8 2.62 19.4 ~.o. 6 0.1 1.6 2.66 15.7 5~.7 0.~ 1.0 2.67 5,8 78.9 ss, v£g, v slty same, v sity same same s ams same same same same sltst same same same same ls, fx same S alii e same, slty same, slty same shale, sity, catc s al~ e s alno These analyses, opinions or interpretations are based on observation~s and materials SUpl)lied by the client to whcqn, and for whr~.e excluxtve and conlidential use, this report is made. The interpretations Or Opinions expreased represent the best judf'jnent of Core l~d~oratories, Inc. (all errors and (~nlssio~m ex- cepted); but Core Laboratories. Inc., and its officers and employees, assume no responsibility and make no warranty or repre.~entatir~m, as to the productivity, proper operation, or profitableness of any oil, gas or other mineral well or sand in connection with which such report is u.~ed or relied upon. CORE LABOR,\ TORIES, 1N C. I'etrolcu m Il csert,oir Engi.ecri,~g DALLAS. TEXAS Lo ca tio n Company MOBT'L__0T~, we. KUPARIIK PP-I~-1 2 c,,~, DIM~0ND ""~- BP-3-389 Field :~]I~D C~_~ Drilling Fluid WI'dB Date ~po, 5-20-76 county_NORTH SLOPY State ALASKA ~Elevation Analysts WSP, RB Remarks DEAN-SWARK CORE ANALYSIS RESULTS (Figures in parentheses refer to footnote remarks) PERM EA BI LITY R ESI D U A L MILLIDARCYS SATURATION SAMPLE DEPTH ] [ POROSITY GRAIN Total Water I~kEMAR KS NUMBER FEET Horizontal Horizontal Oil Maximum] 900[ Vert'ical PERCENT DENSITY %Pore % Pore _~ 26 27 28 29 30 31 32 34-: 35 ,36 37 38 39. 4.1 4.2 45 46 47 48 50 98oo 9801 98o2 9803 9804 9805 98.08 98o9 9810 9811 9812 9814. 9815 9822 982~ 9824. 9827 9828 9829 98)Q 98~ 98~2 98~ 0.2 1. 1.0 1. 0.2 1. O.2 1. 0.1 0.6 1. 25 65 13. · 167 26 18. lOO 45 18. 4o 29 16. 4o 4O 17. 43 34 18. 45 61 17. 2.5 12 12. lO i0 16. 2.9 1.3 i2. 1.6 1.2 11. 20 8.6 13. 23 1.4 16. 0.7 6. 1.6 11. 6.7 2.,6 15. 7oO 10 17. 17 4.5 18. 8.9 13 17. 2.67 lO. 3 2.59 25.2 2.65 2.2 2.67 1.6. 2.68 1 3.7 2.6~ 0.0 2.74 19.9 2.66 23.4 2.62 38.5 2.71 14.5 2.71 13.7 2.73 17.6 2.68 18.9 2.58 24.7 2.68 iS.1 2.66 12.6 2.64 19.5 2.94 18.5 2.73 19.9 2.76 4.8 2.76 12.4 2.75 14.7 2.76 16.3 2.76 17.8' 2.g0 14.3 59.3 shale, 66.7 same 48.0 same 71.4 same 38.5 same 7 4.3 same 20.8 ss, 2 4.6 same 39.7 same 32.8 same 31.9 same 30.7 . same 31.3 same 2 6.8 same 16.7 same 32.3 ss, 26.1 ss 50.2 ss, 44.5 ss, 79.8 ss, 68.0 same 56.7 same, 53.6 same, 52.3 same, 57.5 same, f-mg fg, slty slty, calc f-rog, f-mg, sid, sid, sid, sid, sid, pyr sid pyr ely These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and cnnissicnks ex- cepted); but Core Laboratories. Inc.. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operation, or profitableness of any oil. gas or other mineral well or sand in connection with which such report is used or relied upon. CORE LAi3OI{,.\TOlllES, liNC. Pc troleu tn R escrv o ir Engin ccrin,q DALLAS, TEXAS Compa.y___MOBIL 0IL CORP We.____KUPARUK 22-11-12 Fi~, d3~ILD CAT county.___~0RrpH SLOPE State AI.ASKA Location_ Formation Cores DIAMOND Drilling Fluid l/bt?~q'~ Elevation Remarks DEAN- STARK · Date Report Analysts ~l~p CORE ANALYSIS RESULTS (Figures in parentheses refer to footnote remarks) PERM EA BILITY R ES I DU A L MILLIDARCYS SATURATION · SAMPLE' DEPTH [ POROSITY GRAIN Total Wa REMARKS NUMBER FEET Horizontal Horizontal Oil ter MaximumI 90° Vertical PERCENT DENSITY % Pore %Pore 51 52 53 54 55 56 57~ . 5:8 59 60 62 63 64 ,·65 66 67~ 68 70 72 73 78 75 9835 9836 9837 9838 9839 9840 98.41 .-9842 9843 9844 9845 !9846 9847 9848 9849 9850 9851 9852 9853 9854 985,5' 985~6 9857 9858 9859 16 25 14 35 9.0 14 5.4 ¸ 6.1 9.2 3.5 17 20 20 17 22 37 34 16 16.5 2.84 18.7 48.5 ss, f-g, sid 3.8 19.7 2.64 17.3 48.6 same, sial 5.0 17.7 2.66 22.3 43.7 ss, vf-mg 24 17.0 2.83 20.7 4.2.6 ss, f-mg, sial 11 16.0 2.67 14.2 49.1 ss, vf-fg 10 17.9 2.65 15.7 50.5 same 5.7 16.1 2.70 13.2 52.9 same 3.2 13.5 2.86 14.3 46.9 same, pyr 3,2 16.5 2.74 13.0 50.0 same, pyr 4.1 15.8 2.70 17.5 46.3 same 11 18.'5 2.73 12.0 47.9 same 21 17.7 2.77 15.7 44..3 same 87 20.1 2.69 12.0 52.8 same 9.0 19.5 2.67 24.5 36°9 ss, f-rog 28 15.7 2.77 6.5 53.0 same 3.5 16.8 20-83 17.0 42.7 same 33 18.1 2.69 16.7 33.7 same 3'7 17.~6 2.73 15.9 41.0 same 0.9 17..8 2.67 22.5 4.1.1 same 17 18.3 2.66 19.4 36.3 ss, fg 33 18.3 2.70 21.9 36.4 same 36 18.1 2.68 i9.8 58.6 ss, mg 4,1 19.6 2.67 1.3.0 54.0 ss, fg 6.9 18.5 2.82 20.3 51.2 ss, f-mg, pyr 52 2202 -2.70 ·19.2 52.5 same These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom. and for wh~;e excltr-dve and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and owntssiorm ex- cepted); but Core Laboratories, Inc.. and its officers and employees, assume no responsibility and rmake no warranty or representations, as to the productivity, proper operation, or profitableness of any oil, gas or other mineral well or sand in connection with which such report is used or relied upon. Company MOBIL 0IL QORP. KUPARUK 22-11-12 WT T,T') ~Aq~ cou.ty . NORTH S!,0PE State Location, COI{E I,AI3OI{.\TORIES, 1NC. l'etroleu m R e. sm'~oir l'Stgitwcring DALLAS, TEXAS AI, ARYA , Formation Co~es D~AMOND Drilling Fluid W Elevation P. emarks D'R. AN-STAR¥ CORE ANALYSIS t~ESULTS (Figures in parentheses refer to footnote remarks) PEP. M EA BI LITY P. ES1DUA L MILLIDARCYS SATURATION SAMPLE DEPTH } [ POROSITY GRAIN I '" KEMARKS NUMBER FEET Horizontal Horizontal Oil Total Water Maximum 90° Vertical PERCENT DENSITY % Pore % Pore 76 77 78 79 8O 81 82 8'; 86 87 88 89 90 91 9.3 94 95 96 97 98 99 100 9860 9861 9862 9863 9864 9865 9866 '. 9867 19868 9869 ~9870 19871 9872 9873 9874 9875 9876 9877 9878 9879 98189 98~81 9882 9883 98'84 4.5 29. 14.6 3.02 16.6 57.3 ss, fg, sid 14 23 17.8 2.73 20.8 50.0 same 18 50 18.9 2.84 16.6 53.1 ss, mg, pyr 57 56 21.3 2.70 20.4 47.2 same 8.9 2.4 16.7 3.01 18.9 53.5 same, pyr 1.1 1.6 12.1 2.76 1.7 78.7 ss, vf-fg, sid 5.4 1.7 15.6 2.81 11.3 59.3 22, fg, cty 15 19 19.0 2.73 16.5 46.5 ss, vf-fg 26 24 19.9 2.69 18.3 41.3 same 7 1.9 19.5 2.68 19.7 41.3 same 8.0 17 18.2 2.68 12.0 52.4 same 82 32 21.0 2.77 13.3 55.9 ss, mg 1.4 4.7 12.2 2.65 26.8 37.3 ss, vf-fg 30 37 18.8 2.74 12.8 53.9 ss, f-rog 20 16 19.5 2.66 12.0 51.3 ss, fg 3 7.7 18.5 2.67 15.1 51.5 same 49 26 20.2 2.70 17.5 49.0 ss, f-mg 5 44 21.5 2.71 1l[.4 49.5 same 37 38 18.3 2.86 15.2 44.2 same 26 59 ,22.6 2.71 13.0 49.4 ss, m-cg 8.2 12 16.0 2.69 12.1 50.8 ss, mg, pyr 22 6.1 17.5 2.70 20.9 37.8 ss, f-mE 4, 33 1 9.3 2.7 5 10. 6 58.1 same 27 36 19.3 2'~76 17.8 45.8 same 71 62 22.7 2.70 17.5 48o.0 same These analyses, opinions or interpretations are based on observatiorm and materials supplied by the client to whom, and for whr~.;e exclu_sive and confidential use, this report is made. The interpretations or opinions expressx-d represent the best judgment of Core I.aborat~>ries., Inc. (all errors and {maissions ex- cepted); but Core Laboratories, Inc., and its officers and employees, assume no responsibility and make no warranty or rcpres, entati(ms, as to the productivity, proper operation, or profitableness of any oil, gas or other mineral well or sand in connection with which such rel~ort is used or relied upon. Company MOBIL OIL CORP. we, KUPARUK 22- t I - 1_ 2 Field WTI,D C AT County NORTH SLOPE_state ALASKA Location C()I{E I~AI~OI~ATOI{1ES, INC. l'e!ro leu m Il cser v o b' l"m/4in e ering DALLAS, TEXAS Formation Cor~s DT/~MOND Drilling Fluid Elevation Remarks DEAN-S~ARK CORE ANALYSIS RESULTS (Figures in parentheses refer ~o footnote ~emarks) PERMEABILITY RESIDUAL MILLIDARCYS SATURATION SAMPLE DEPTH , [ " POROS1TY GRAIN Total Water NUMBER FEET Horizontal[ Horizontal PERCENT DENSITY Oil Maximum 90° Vertical % Pore % Pore Page 5 of.-- ~[ 2 l:i~e BP- 3-3&9 Date Report 5' _2__Q_- 7 6 .... Analysts ?'JSP, RB 101 102 lo3 lo4 lo5 lo6 lo7 1,95 io9~ 11o ii6 ii? 119 1'20 122 9885 9886 9887 9888 9889 9890 9891 9892 9893 9894 9895 19896 9897 989,8 9899 9900 99ol 99o2 9903 9904 99o~ 99~6 9907 99o8 9909 78 7o 21.8 2.70 18.o 45.8 143 131 23.0 2.75 18.9 45.9 25 80 20.8 2.68 17.1 45.7 119 89 22.9 2.70 12.8 43.8 89 80 22.3 2.70 20.4 34.8 30-, 82 20.0 2.77 9.3 4~8.5 64 17 22.1 2.68 17.2 46.8 71 24 21.5 2.71 14.6 43.1 57 60 21.1 2.71 ~8.2 40.1 18 ' 42 18.4 2.73 16.0 44.6 9.2 6.4 17.5 2.69 16.7 4~.8 1.0 5.1 13.4 2.70 15.4 41.7 31 3.8 21.7 2.70 17.6 50.0 56 49 22.0 2.69 11.8 49.1 42 36 20.7 2.67 11.5 48.5 33 23 20.0 2.71 13.o 46.8 64 75 21.8 2.76 13.9 46.1 82 51 22.0 2.78 14~5 44.2 73 39 24,0 2.70 8.0 56.9 24 87 20.5 2.73 18o2 47.1 105 98 22.3 2.75 i5.5 ¥3.0 40 62 17.6 2.86 18~o 37.8 119 io6 23.7 2.74 i7.4 42.9 143 112 22.7 2.76 1 3.2 44.8 91 6~ ~9.6 2.75 13.9 41.7 REMARKS ss, fg same same same same same same same same same ss, vf- fg ss, mg ss, f-mg ss, fg s amc ss, f-rog same same S am e same ss, ra~, sid came, si'd same, s~d same, sid same, sid These analyses, opinions or lnterl)retatlons are based on ob~,rwdions and materials sol)plied by the client to whom, and for who~;o exchvdwr and confidential use, this report is made. The interpretations or opinJcms expres_~-d represcmt the best judgment of Core I.aboratories, Inc. (all errors and (mds.si(m.q ex- cepted); but Core L~boratories, Inc., and its officers and employees, assume no responsibility and make no warranty or representaticms, as to the productivity, proper operation, or profitableness of any oil, gas or other mineral well or sand in connection with which ~uch report is used or relied upon. Compa.y I'~OBT'I', OTL CORP. We. TKIH:ARIIK 22-11 -1 2 F~e~d WILD CAT Cou.,y NORTH SLOPE _ State ALASKA Location CORE I~AI3OIL\TOI{IES, 1NC. Petroleum Reservoir Enginecrit~g DALLAS, TEXAS Formation Cores DI AI~,~0ND Drilling Fluid Elevation Remarks DEAN-STARK CORE ANALYS1S RESULTS (Figures in parentheses refer to footnote remarks) Page 6 of ~. fO I:,e BP- 3-389 Date Report,. f--20--76 WSP ~ RB Analysts PERIvlEA BILITY RESIDUAL MI LLIDARCYS SATURATION SAMPLE DEPTH ] POROSITY GRAIN I NUMBER FEET Horizontal Horizontal PERCENT DENSITY Oil Total Water Maximum 90° Vertical % Pore % Pore 126 127 128 129 130 131 132 · 133 134 135 138 · .!-39 "4-0 15o 991o 99il 9912 99i 3 99i4 9916 9917 9918 9919 992O 9921 9922 9923 992!4 9925, 9926 9927 9928 9929 9930 993~ 9932 9933 9934 84 lo5 13 .56 84 63 0.6 1.6 0.3 12 5.7 3,2 0.6 302 89 28 25 2i 4,5 33 27 0.4 0.5 ~.5 14 B. EMARKS 77 20.9 2.80 18.2 42.0 ss, rog, sid 63 20.2 2.79 9.0 48.7 same, sid 63 15.5 2.94 14.5 46.6 same, sid 28 20.4 2.84 i8.0 39.3 same, sid 86 22.0 2.71 12.2 43.8 same 24 20.4 2.74 1,3.8 57.7 same 1.6 12.9 2.79 6.4 72.2 ss, vf-£g, sial 0.9 13.3 2.67 8.8 61.6 same, sial 8.9 10.2 ~2.72 9.5 74.7 ss, vfg 7.7 16.0 2.67 11.3 56.0 ss, £g 2.9 14.7 2.73 11.8 56.8 same 10.8 12.7 2.69 7.7 62.2 ss, vf-mg 1.0 12.3 2.75 4.6 72.1 ss, vfg 65 24.1 2.64 15.1 58.6 ss, m-cg 64 22.0 2.69 10.7 61.6 same 35 18,9 2.70 15.6 55~7 ss, f-rog 6.4 18.0 2.69 '17.2 49.2 same 15 17.7 2.71 12.9 60.0 same 25 18.2 2.71 17.6 55.4- ss, mg 28 17.3 2.71 15.5 57.4 same 10.4 17o.9 2.70 14..8 59.2 sarae O. 3 8.2 2.72 7.5 81.1 ss, 1 .'1 8.7 2.71 5.2 82.8 same 3.8 12.9 2.6'7 1.4 76~ 8 same 12 16.9 2.75 14.4 54.3 ss, fg These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom. and for whose exch£,dve and confidential use, this report is made. The interpretations or opinions expressed represent the best judgrnent of Core Laborator/es, Inc. (all errors and missions ex- ceptecl); but Core Laboratories. Inc., and its officers and employees, assume no responsibility and make no warranty or represent~aticms. ,as to the productivity. proper operation, or profitableness of any oil. gas or other mineral well or sand in connection with which such report is used or relied upon. Com~an~. MOBIL OIL CORP. wd, KUPARUK 22-11-12 Fie~ILD CAT County NORTH SLOPY State ALASKA Location CORE I,AI:~OI:{:\TOI{IES, INC. ]~e troleu m 1{ est,ruoir £ngin coring DALLAS, TEXAS Formation Cores DI AI',ION D Drilling Fluid WBI~ Elevation ~em~kg DEAN-STARK P~ge 7 or--. 12 File BP- 3- 389 Date Report _5-- 20- 7 6 ^,~aly.~ WSP. RB CORE ANALYSIS RESULTS (Figures in parentheses.refer to footnote remarks) PER. MEABIL1TY P, ESIDUAL M1LLIDARCYS SATURATION SAMPLE DEPTHI " PoROsITY GRAIN REMARKS NUMBER FEET Horizontal Horizontal [ Oil Total Water Maximum 900I Vertical PERCENT DENSITY %Pore %Pore 151 152 153 154 155 156 157 1 '58 159,' 16o 162 ~.67. 1,69 17o 172 ~75 9936 27 9937 3. 5 9938 64 9939 45 9940 16 9941 6.4 9942 15o · 9943 :1.54 9944 35 9945 26 9946 48 9947 91 9948 lO7 994~9 28 9950 19 995i 82 9952 164 9953 77 ' 9954 129 9955 34 9956 82 995? 55 9958 5t 9959 63 996o ;' 96 i4 18.5 2.68 16.6 53.8 ss, fg 40 17.7 2.70 13~0 57.5 same 55 19.7 2.68 15.8 56.2 ss, f-mg 12 20.1 2.77 26.1 54.2 ss, mg 55 19.5 2.73 14.1 62.9 ss, f-rog '35 16.9 3.03 10.6 71.4 same 91 22.2 2.70 15.7 57.7 ss, mg 101 2Z,~.1 2.68 13.5 61.2 same 30 t9,9 2.69 i5.2 59.6 ss, fg 31 20.2 2.68 14.2 60.7 same 61 21.0 2.69 15.6 54.1 ss, f-rog 37 22.3. 2.68 17.7 51.0 same 35 22,9 2.68 13.8 56.5 ss, mg 34 18.3 2.69 20.1 52.1 ss, f-mg 19 18.6 2.68 17.0 55.2 same 38 22.3 2.67 i8.2 50.8 ss, mg 26 27.3 2.66 14.2 61.5 ss, m-cg 76 22.2 2,71 19.1 51.1 ss, f-rog 80 22.1 2.71 15.0 50.8 same 84 19.4 2.84 20.9 46.1 ss, fg 74 21.7 2.7i 19.8 47.2 same 24 20.7 2.70 19.7 48.9 same 42 20.6 2.68 20.2 48.4 same 2.1 21.5 2.70 11'~.1 59.8 ss, mg 115 22.1 2.75 15.4 58.4 same These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom. and for whose exclu_give and confidential use, this report is made. The interpretations or opini(ms expre~ssed represent the best judgment of Core Laboratories, Inc. (all errors and omissioxm ex- cepted); but Core Laboratories, Inc., and its officers and employees, assume no rewponsibility and make no warranty or representatic~ns, as to the productivity, proper operation, or profitableness of any oil, gas or other mineral well or sand in connection with which such report is used or relied upon. Company MOBIL 0IL cORP. We. KIJPAR'[JK 22-1 t -1 2 County .NORTH SLOPE - State . Location' ALASKA CORE I,ABOII.,VI'OIIlES, INC. Petroleum Reservoir E,v,,ineerit¥4 DALLAS, TEXAS Formation Cores DT Ah~OND Drilling Fluid .~_~M Elevation Remarks DE/~N-STARK }'ag~ 8 of 1 2 File BP- 3- 389 Date Report ~.5-- 20- 7 6 CORE ANALYSIS RESULTS (Figures in parentheses refer to footnote remarks) SAMPLE NUMBER 176 177 178 179 18o 181 182 184 i8~' !86 1'37 188 189 79c~ 191 192 ~9~- 194 195 196 197 198 200 DEPTH FEET PERMEABILITY l MILLIDARCYS i POROSITY Horizontal Horizontal PERCENT Max imu m 90° Vertical 9961 9962 9963 9964 9965 9966 9967 9968 9969 997o 9971 i9972 9973 997,4 9975 9976 9977 9978 9979 998O 998!~ 99~32 9983 9984 99~5 GRAIN DENSITY RESIDUAL SATURATION Oil [Total Water % Pore % Pore 115 96 .22.5 2.7 6 14.9 57.9 ss, mg 98 101 21.8 2.78 17.0 58.2 same 8C) 77 20.9 2.74 13.9 58.6 same 9/-I, 98 21.3 2.77 13.0 58.7 same 51 28 20.1 2.74 16.5 55.7 ss, f-rog 6.1 33 14.6 2.72 12.0 48.9 ss, fg 59 44 20.1 2.72 18.3 44.1 ss, mg 3.2 1.3 14.1 2.72 10.6 55.2 ss, m-cg 14 45 16.7 2.70 12.8 49.8 same i22 49 2t.2 2°74 14.5 46.8 same 117 103 21.5 2.77 11.9 49.3 same 115 94 21.8 2.75 14.8 63.6 same 80 61 19.1 2.74 17.5 55.3 ss, f-rog 26 15 20.6 2.75 16.9 58.4 same 140 63 22.2 2.69 18.2 59.5 same '173 48 23..7 2.75 13.8 65.0 ss, m-cg 26. 5.7 19.1 2'75 8.3 68.0 ss, mg 71 77 19.4 2.74 11.3 63.9 same 190 152 21.8 2.72 14.5 60.9 same 110 136 20.9 2.74 18.3 56.2 same 351' 260 23.3 2,68 13,5 58,7 same 5~ 119 18.0 2.82 114.4 60.6 ss, f-rog 262 115 23,1 2.?2 4.8 66.4 ss, 1.2' 1.? 14.2 2.71 0.? 66.8 ss, vfg 342 211 23.1 2.71 1!..4 59.i ss, m-cg, REMARKS pcb These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom. and for whcn;e exclusive and confidentlM use, this report is made. The interpretations 'or opinions express~ represent the be~ judg~nent of Core LaboraU~ries. Inc. (all errors and o~nission.,~ ex- cepted); but Core Laboratories, Inc.. and its officers and employees, a~me no responsibility and make no warranty or repres, enUations, as to the productivity, proper operation, or profitableness of any oil. gas or other mineral well or sand in connection with which such report is used or relied upon. Company _T'.-";Oi3:.~ NTT gORP WeU KIIPARU~ ~-~1-12 Field WII,D fi. AT County NORTH SLOPE State ALASKA Location CORE I,,\13OI~,ATORIES, INC. Petroleutn Reservoir Engi~eerit%, DALLAS, TEXAS Format io {1 Cores DIAMOND DriUi,~g Fluid WBM Elevation Remarks Page__ 9 ,,, of File-.~.P-- 3-- 38 9 Date COKE ANALYSIS RESULTS (Figures in parentheses refer to footnote remarks) PERMEABILITY RESIDUAL MILLIDARCYS SATURATION SAMPLE DEPTH i [ POROSITY GRAIN [ REMARKS NUMBER FEET Horizontal Horizontal PERCENT DENSITY Oil Total Water Maximum 90° Vertical % Pore % Pore 201 202 203 204 205 206 207 208 209 21(~ i211 212 213 214 215 216 21 ~; 219 220 221 222 223 224 225 9986 9987 9988 9989 9990 9991 9992 9993 9994 9995 9996 9997 9998 9999 10000 1OOO1 10002 10003 1000~ 10006 10007 10008 10'009 1OO1O 10011 241 147 14O 7'.6 11 19 9.9 0.5 0.7 2.1 372 194 246 206 4~9 442 66 .129 91 26 304 _5o? 316 239 /491 o 68 136 7.7 9.2 12 6.4 3.5 3.2 26 84 143 192 145 ';. 69 190 26 68 0.7 25 374 5/,6 117 199 274. 21.6 2.70 12.9 59.8 ss, m-cg 21.2 2.70 15.8 54.5 same 18.8 2.70 14.3 _56.7 sarae 16.6 2.68 5.2 63.2 ss, vfg 17.1 2.67 15.3 54.9 same 18.3 2.66 16.5 55.3 ss, vf-fg 18.0 2.69 7.7 67.8 same 10.0 2.73 4.1 66.6 ss, vfg 10.3 2.69 7.0 69,5 same 13.0 2.77 2.6 76.5 ss, fg, sial 21.9 2.72 19.0 49.0 ss, mg 20.3 2.79 17.7 50.1 ss, f-rog, sid 21.7 2.73 13.8 56.9 ss, m-cg 21.9 2.80 13.5 62.8 same, sial 25.5 2.73 19.9 55.8 same, cly.nod, 27.4 2.70 13.4 61.7 same 19.9 2.73 15.9 51.0 ss, f-mg 18.1 2.95 1~.4 62.7 ss, m-cg, 20.0 2.77 13.2 53.1 ss, f-rog 10.2 3.00 2.~ 69.6 same, sid, pyr 23°8 2.76 12.3 57.6 ssm m-cg 26.3 2.70 8.4 61.5 same, pcb 25.1 2.72 10.8 69.2 same, peb 23.1 2.71 9.8 58.9 ss, mg 25.4 20 68 10ol _58.7 same sc pe] These analyses, opinions or interpretations are based on ob~,~ervations and materials supplied by the client to whom. and for whose excluxtve and confidential use, this report is rnade. The interpretations or opinions expressed represent the best judgment of Core Laboratories. Inc. (all errors and omissiorm ex- cepted); but Core Laboratories, Inc., and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operation, or profitableness of any oil, gas or other mineral well or sand in connection with which such report is used or relied upon. CORE LABOI{.\TOI{1ES, INC. l'etroleu m l{ eservoir Engineer DALLAS, TEXAS Company-. ]]d C) ]~ -[ '[, OTI, CORP. We, KIIPARIIK 22-1t-12 Field WILD CAf[! County NORqqq SLOPE _ State ALASKA Location , Format ion core~ DI AMOND Drilling Fluid . Elevation Remarks DEAN-STARK File BP- 3- 389 Date Report--__~- 20-7 6 . .. Analysts ~..~,J..q.P, RE CORE ANALYSIS RESULTS (Figures in parentheses refer to footnote remarks) PERMEABILITY RESIDUAL MILLIDARCYS SATURATION SAMPLE DEPTH [ POROSITY GRAIN 'Fetal Water REMARKS NUMBER FEET Horizontal Horizontal PERCENT DENSITY Oil Maximum 900I Vertical %Pore %Pore 226 227 228 229 230 231 232 .. 233 23~ 231; ~2'36 2,37 238 2.39 24.1 244 245 246 2~7 248 249 25O 10012 10013. 1O014 iool5 1oo17 lOO18 loo19 10020 10O21 10022 10023 !10024 10025 10027 100!28 10029 ioO~o ' lOO31 100.32 too33 100 34 loo~36 10044 lOOb,~ 1 oo~¢6 523 190 239 101 12 192 75 30 51 6.4 0.6 2O ~7 96 70 379 168 36o 25o /42- 6~ 2.8 ~2 46i 25.0 2.73 14.6 54.6 lol 21.3 2 .73 ii .8 ~ ~-2 .6 171 21.3 2.76 11.2 55.3 122 20.4 2.7311.6 58.1 9.6 19.3 2.69 0.0 86.5 ilo 2i.o 2.70 13.1 55.5 15 19.7 2.75 6.8 66.1 27 16.3 2.77 11.5 58.2 '35 18.8 2.74 5.9 66.6 4.0 16.0 2.75 0.0 82.6 '4.1 8.5 2.83 3.2 69.5 8.6 14.2 2.65 0.0 78.7 33 14.5 2.65 0.0 78.9 70 18.7 2.72 9.4 5~.0 171 18.9 2.83 7.3 64.9 332 22.8 2.71 7.4 69.0 145 22.4 2.70 9.2 62.1 557 22.0 2.68 6.1 60.7 136 22.1 2.70 9.3 60.6 426 23.7 2.74 4.4 66.4 31 19.0 2.72 3.8 83.5 9.5 19.0 2.83 1.6 86.3 240 22.4 2.75 0.9 95.3 6.0 15.3 2.67. 0.0 87.9 19. 17.3 2.71 0.0 89.7 ss, same same same ss, fg ss, f-rog same same same same, slty, ss, fg, sid ss, vf-fg same ss, f-rag same SS, same same same same , same , salae, same , ss, ss, m-cg, pcb v peb v peb v pcb v£-fg fg cly peb These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom. and for whce.;e excluxtve and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and missions ex- cepted); but Core Laboratories, Inc., and its officers and employees, assume no responsibility and make no warranty or representaticms, as to the productivity, proper operation, or profitableness of any oil. gas or other mineral well or sand in connection with which such report is used or relied upon. CORE I,AIIOI{ATOIIlES, IN(.:. Pc, trolcu tn R cseruoir Eu~ginccritv4 DALLAS, TEXAS Company NOBII, 0TL CORP. W,ll KIIPARI/K 22-11-17 Fidd WTT,D CA~ County NORTH ~7,OPE State Location AZ,ASKA Formation core~ DT AI~OND Drilling Fluid . Elevation Remarks D~AN-SwARK F~,e ~P-- 5-- 389 l~a,e l~i,,,r, ~ 5- ~ 6 Analyst s J~.~; ~B CORE ANALYSIS RESUL$S (Figures in parentheses refer to footnote remarks) PERMEABILITY RESIDUAL MILLIDARCYS SATURATION SAMPLE DEPTH ] [ POROSITY GRAIN Total Water R. EMARKS NUMBER FEET Horizontal Horizontal PERCENT DENSITY Oil Maximum[ 90°[ Vertical %Pore %Pore 251 252 253 25~ 255 256 257 -. 259 26c ,.261 2,62 263 264 :>.6 ~ 266 269 270 271 272 273 274 275 ~oo47 10048 10049 lOO5O 10051 io052 10053 . loo54 ioo55. 10056 loo57 '10058 ioo59 10060 loo61 loo62 10063 10064 loo65 ioo66 loo67 loog8 10069 10070 10071 16 178 168 13 176 3oo : 94 2O 19 145 1406 1295 1295 262 94 171 1961 1!10 i594 999 1110 1850 136 16i i5 19.3 2.69 .o.o 93.3 2i 19.2 2.70 o.o 93.5 87 22.2 2.73 0.0 94.9 54 22.9 2.74 5.7 78.6 47 16.7 2.77 0.0 91.5 318 22.9 2,70 0.0 89.6 10 24.0 2.71 0.0 93.6 86 21.8 2.69 0;0 93.1 9.0 17.5 2.69 0.0 82.8 61 17.5 2.7~ 0.0 94.1 67 ' 23.0 2.71 0.0 88.7 468 26.5 2.72 0.0 82.8 871 28.2 2.72 0.0 90.5 180 27.8 2.73 0.0 93.8 405 22.7 2.71 0.0 94.7 63 24.2 2.71 0.0 85.2 220 26.! 2.68 0.0 84.0 1443 27.6 2.63 0.0 88.2 416 27.3 2.64 O. 0 91.8 1144 25.7 2.64 0.0 90.6 719 25.9 2.68 o.o 9~ .2 784 24.1 2.72 0o0 92.7 512 26.7 2.70 0o 0 92.4 136 26.2 2.67 o.o 91.6 159 19.3 2.67 o.o 92.1 f-mg SS, same same same same, same ss, m-cg ss, f-rog ss, £g same ss, m-cg, ss, cg same same, same, c ong, same, SS , C-VCg, same, pcb SS , C~, SC sc peb SC peb pe v pcb sdy F.D. sdy F.D. peb pcb same, sc pcb same, sc pcb same, sc pcb same, sc pcb same, sc pcb These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom. and for whose exch~tve and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core I_mboratories, Inc. (all errors and omLssiorm ex- cepted); but Core Imboratories. Inc., and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity. proper operation, or profitableness of any oil, gas or other mineral well or sand in connection with which such repo~ is used or relied upon. Company MOBIL 0IL CORP. w~, ~UPARUK 22-11-12 Field W!_I,D CAT County NORTH SLOPE State ALASKA Location CORE I~ABOI/,\TOI~IES, INC. l~e troleu tn R esert, oir Engb~ecring DALLAS, TEXAS Formation Page 1 2 of 1 2 co~es DIA~OND Fm,_~BP- 3- 38-9 Drilling Fluid ~lBr~ Date Report 5-20-76 Elevation Analysts- WSP: RE Remarks DEAN-STARK CORE ANALYSIS RESULTS (Figures in parentheses refer to footnote remarks) PERM EA BILITY R ESI D UA L MILLIDARCYS SATURATION SAMPLE DEPTH POROSITY GRAIN i I~.EMARKS NUMBER FEET Horizontal Horizontal Oill Total Water Maximum 90° Vertical PERCENT DENSITY % Pore % Pore 276 277 278 279 28o 281 282 284: 285 2i86 207 288 289 ~':90' 29~ 292 294 10072 10073 10074 10075 10076 ~0077 lo078 z0079 1OO8O 1008i 1oo82 i008 3 10084 1o085 10086 10087 10088 10089 10090 40 197 18.0 2,73 0.0 89.8 ss, f-rog 703 634 19.3 2.97 0.0 88ol ss, rog, pyr 258 350 25.4 2.63 O. 0 94.7 same -285 306 21.8 2.64 0.0 95.9 same 555 547 24.6 2.64 0.0 94.7 ss, m-cg 288 175 22.1 2.83 0.0 95.8 same, pyr 629 109 24.5 2.66 0.0 83.3 same 49 49 40 16.4 2°65 0.0 8i.3 cong, sdy 6.3 4.6 3.1 12.1 2.92 0.0 80.5 same, v pyr 3.2 2.0 1,4 10ol 2.97 0.0 75,3 same, v pyr 23 20 19 10.6 2.74 0.0 73.1 same, pyr 28 21 5.8 8.9 2.85 0.0 70.2 same, pyr 47 18 8.2 10.5 2.74 0.0 75.5 same, pyr 29 24. 26 10.0 2.76 0.0 66.3 same, pyr 29 22 16 11.3 2.78 0.0 71,4 same, pyr 28 21 12 9.9 2.71 0.0 83.5 same, 26 33 26 9.6 2.70 0o 0 67.4- same 39 26 · 15 11.7 2.65 0.0 72.2 same 86 55 33 13.2 2.66 0,0 72.9 same F.D. These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom. and for whose exclusive and cortfidentLal use. this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and oral.ions cepted); but Core Laboratories, Inc., and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operation, or profitableness of any oil, gas or other mineral well or sand in connection with which such report is used or relied upon. Company. Well Field County Location, CORE LABOIiATOItlES, 1NC. Petrolcu tn R eserv oir Engb~eering DALLAS, TEXAS MOBIL 0IL CORPORATION KUPARUK 22-11-12 Formation Cores S I DE'WALL WILDCAT Drilling Fluid WBM NORTH SLOPE State,. ALASKg.. Elevation Remarks 'DEAN-STARK ANALYSIS Page __ of. }rile BP-3-389 Date Report 5/24/76 WSP Analysts .... CORE ANALYSIS RESULTS (Figures in parentheses refer to footnote remarks) PERM EA BI LITY R ES 1DU A L MI L LI DA RCYS SA]' U RATION SAMPLE DEPTH POROSITY GRAIN Total Water NUMBER FEET Horizontal Horizontal Oil Maximum 90° Vertical PERCENT DENSITY % Pore ] % P__re__ REMARKS 3140 3150 3575 3582 3592 3606 3640 3852 3858 .3866 3876 3886 3970 4186 i4208 4520 4532 .t 4875 5280 5288 5'300 5345 535'8 5390 5428 5436 54418 549 1 5498 5508 551'8 5577 558 62 97 6076 2395 48'2 385 2102 299 '235 398 145 114 2696 437 543 142 725 869 19 4 6 10 32 16 99 36 75 47 34 102 115 29 51 .5 .5 29.6 2.63 5.8 71.6 ss, vfg 32.5 2.70 4.7 69.4 ss, vfg 35.0 2.63 36.8 43.4 ss, f-rag 30.7 2.64 42.3 37.8 ss, f-rag 31.3 2.65 33.4 43.8 ss, f-mg 29.9 2.73 34.7 51.6 ss, f-mg, ely 33.6 2.63 26.4 59.8 ss, f-rag 24.4 2.64 16.3 68.3 ss, f-mg, v ely 29.3 2.65 17.8 69.7 ss, ra-cg 29.1 2.64 27.9 57.4 ss, ra-cg 29.8 2.66 27.2 61.8 ss, m-cg 27.8 2.64 22.6 63.9 ss, m-cg 31.4 2.66 16.2 75.8 ss, m-cg 28.4 2.62 24.6 67.3 ss, ra-cg 21.6 2.63 17.6 74.6 cortg 28.1 2.67 8.7 81.2 ss, f-mg 31.1 2.65 5.4 83.6 ss, f-mg 31.8 2.67 12.7 78.0 ss, v f-rag 27.2 2.67 8.8 82.3 ss, fg 25.7 2.78 26.4 49.8 ss, vfg 23.0 2.71 4.9 85.0 Ss, vfg 27.0 2.71 10.3 72.8 ss, vfg 27.6 2.62 18.2 67.1 ss, fg 23.4 2.60 12.6 71.3 ss, vf-fg 30.3 2.71 14.5 70.8 ss, f-rog 27.6 2.71 13.9 69.1 ss, f-rog 26.9 2.66 18.8 64.8 ss, fg 24.8 2.67 12.7 72.2 ss, fg 25.0 2.67 7.6 79.3 ss, fg 28.9 2.67 16.4 71.3 ss, fg 2'6.3 2.74 20.7 70.8 ss, fg 25.2 2.64 18.8 64.7 ss, fg 27.7 2.63 23.2 59.5 ss, fg 'lq~ese analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose cxclu.';lve and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and cnnlssiorm ex- cepted); but Core Laboratories, Inc., and its officers and employees,' assume no responsibility and make no warranty or representations, as to the productivity, proper operation, or profitableness of any oil, gas or other mineral well or .sand in connection with which such report is used or relied upon. Company Well. Field ' Cou n ty, Location MOBIL OIL CORPORATION CORE I,AI~OI{ATOIIlES, lINC. Petroleum Reservoir Engineering DALLAS, TEXAS Format ion KUPARU K 22-11-12 Cores SIDEWALL. WILDCAT Drilling Fluid WBM NORTH SLOPE State AId~_S~ Elevation Remarks DEAN-STARK ANALYSIS P a g e File 2 2 BP-3-389 Date Report 5/24/76 WSP Analysts CORE ANALYSIS RESULTS (Figures in parentheses refer to footnote remarks) SAMPLE NUMBER DEPTH FEET PERMEABILITY 1 MILLIDARCYS i ]POROSITY Horizontal Horizontal PERCENT Maximum. 90° Vertical GRAIN DENSITY SATURATION Oil Total Water % Pore % Pore 5782 30. 21.2 2.67 17.2 60.9 ss, fg 5787 17 21.1 2.65 11.8 75.6 ss, fg REMARKS These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom. and for whose excluxtve and confidential use, this report is made. The interpretations or opinions expressed r~present the best judgment of Core L.aboratories, Inc. (all errors and ornissiorm ex- cepted): but Core lmboratories, Inc., and its officers and employees, assume no responsibility and n-rake no warranty or representations, as to the productivity. proper operation, or profitableness of any oil, gas or other mineral well or sand in connectkm with which such report is used or relied u~on. CORE LABORATORIES, INC. Petroleum Reservoir E,~ineering DALLAS/ TEXAS 75247 June 1, 1976 Mobil Oil Corporation P. O. Box 5444 Denver, Colorado Attention: Mr. Dick Wood Subject: Core-Analysis Data Kuparuk 22-11 - 12 Well Wildcat Field North Slope, Alaska Gentlemen: Diamond core equipment and water base drilling fluid were used in extracting core from the subject well. These cores were pre- served in plastic a~d submitted to our Anchorage laboratory For permeability, pore;ity, grain density, and ~luld saturation deter- minations. The results of these analyses are presented in the accompanyi ng report. We sincerely appreciate this opportunity to serve you and trust we will be called on again in the' future. Very truly yours, CORE LABORATORIES, INC. James A. Cusator District Manager JAC:sme UNITED STATES CANADA SOUTH AMERICA EUROPE AFRICA a u S t ~ A L I A ASIA MOBIL KUPARUK 22-11-12 Sidewall Sample__Description 1. 9761' 2. 9769' 3. 9757' 4. 9755' 5. 9753' '6. 9752' '7. 9749 ' 8. 9746' 9. 9660' 10. twin 11. 9510' 12. twin. 14. twin 15. 9262' 16. twin 17. 9144' 18. twin 19. 9030' 3/4" Sandstone very'fine-fine medium grey quartz very weli sorted subangular poor to fair gold fluorescence poor to fair yellow gold cut fluorescence, no visible cut, non calcareous. 3/4" Sandstone very fine-fine as above, fluorescence spotty to even gold-yellow, cut as above. 1/2" Sandstone as-above, clayey, poor porosity and permeability dull yellow fluorescence uneven, pogr to fair dull yellow cut fluorescence. 1/2" Sandstone as above, no fluorescence, very faint milky yellow cut fluorescence. 1/2" Sandstone as above, inclusions clay very poor porosity and permeability, medium-dark grey, no fluorescence, very poor crush but milky yellow fluorescence. 1/2" Sandstone as above, trace 10% very poor fluorescence very poor crush cut as above. 1/2" Sandstone very fine-fine black grading white, very shaley calcareous matrix, few spots fluorescence, very poor yellow crush cut fluorescence. 1/4" Clay, sandy, soft soluble medium grey-brown, no fluorescence 1 1/4" ~Clay,. dark grey, soft, soluble, no fluorescence. 9660' 1 1/2" Clay as above, sub fissile 9510' 1 1/2" Clay .as above 9390' '1" Clay, medium dark grey 9262' 1 1/4" Clay, brown grey, s~ft, 9144 ' NR NR . 20. twin 21. 8900 22. tWin 23. 8835' 24. 7950' 25. twin · 26. 7900 27. twin 28. 7850' 29. twin~ · 30. 7800 ' · · 31, 9070" 32. 8985' 33.' 8843' 34. 7850' 3.5. ~7750' 36. twin 37. 7700' 38. 7700' 39. 7650' 40. 7650' 41. 7600 42. 7500' 43. twin 44. 7460' 45. · twin 9030' NR NR 8900 NR. NR 2" Clay, soft, brown-grey, sub fissile,' no fluorescence. 7950 ' NR 7900 NR· Clay, brown-grey, soft, massive, soluble. NR 7850 ' NR · 2" Clay, soft brown-grey, blocky, massive, no fluroescence.. 3/4" Siltstone, brown-grey,' slightly calcareous, clayey, no fluorescence, milky white cut fluorescence, no visible stain or visible cut. NR NR all 7750' Clay,.dark grey-brown, silty, slight micaceous, no fluorescence, no cut Clay,~.:~red-brown, slightly~'imicaceous Slight calcareous, no fluroescence. Clay, red-brown, splintery 2" twin Very slight calcareous · 2" Clay,'..brown-grey, soft, soluble 2" twin Massive, very slight calcareous 1 1/2" Clay, red-brown, massive, slightly calcareous, pyrite -NR 7500' NR NR 7460' NR -3- 46. 7426' 47. twin 48. 7400' 49. 7400' 50. 7360' 51. 7360' 52. 7310' 53. 7310' 54. 7255' 55.. 7214' ~56. '7070' - . 57.. 7070' 58. 7035' 59. twin 60. 7035' 61. 7550' 62. 7280' 63. twin 64. 6982' 65. 66. 67. 68. 6930' 6930' 6840' twin 6772 2" Clay, dark-grey, soft, massive, calcareous 7426' 1 1/2" 2" twin NR. Clay, dark grey, m'assive, NR 2" twin Clay, dark grey-black, .massive, calcareous. ,! NR soft Shale, blaCk, sub fissile, fossiliferous, slightly calcareous 1 1/4" Shale as above 1, Shale as above, .slightly calcareous NR 1 1/2" twin Clay, medium-dark grey, Clay, pencil-lead grey, soft, massive. soft, soluble, sub fissi~ soluble, mica sheen, 7035' NR twin 2" 1, ':'clay,,~ ~grey-brown,' soft, sOluble, slightly micaceous, massive. 1 1/2" Cl~y, black-.dark grey, sub fissile, splintery, firm very slightly calcareous .... 6982' NR 1 1/2" Shale, grey-black, s~lintery-blocky, mica sheen, very slightly calcareous 1 1/2" twin - · . 2" Clay, firm, massive, 1/2" Clay, soft, soluble, 6772 NR 1 1/2" Clay, dark grey-black, calcareous pencil lead grey dark-medium grey, massive soft, soluble, massive, non- -4- 70. 6760' 71. 6760' 72. 6755' 73. 6745' 74. twin 75. 6740' 76. 6735' 77. 6720, 78. 5787' 79. 5782' 80. twin 81. 5582' 82. 5577' 83. 5518' 84. 5508' 85. 5498' 86. 5491' 1 1/2" twin 1/2" ' 'Siltstone, medium-dark grey, flaky, friable tight clayey, no fluorescence, no visible cut, milky white cut fluorescence. 11 Clay, medium-dark grey, soft, soluble, no fluorescence milky white-pale yellow cut fluorescence, no visible cut, faint petroleum odor. 11 Clay, as above, no fluorescence, no visible cut, faint petroleum odor, very pale white cut fluorescence. 6740' NR 1 1/2" Clay, as above, calcareous, no fluroescence, slight visible cut, very pale brown, straw-gold cut fluorescenc petroleum odor. NR 1 1/2" Siltstone, medium grey-brown, laminated with light grey calcareous, massive,· no fluorescence, no visible cut, no cut fluoresCence. 1 1/4" Sandstone, .fine-medium grained brown, friable, slightly calcareous, trace pyrite, fair porosity and permeabilit~ gold-brown fluorescence, a~er visible cut, yellow-gold fluorescence cut. 1 1/2" Sandstone, as above, show, as above 5782' 11 Sandstone, fine brown-grey friable unconsolidated non- calcareous, fair porosity and permeability, slight petroleum odor, brown-gold fluorescence, pale amber visible cut, milky white cut fluorescence. ,! sandstone, fine-medium grained brown-grey friable-firm non-calcareous, trace mica, gold-brown fluorescence, occasionally spotty, fair porosity and permeability, amber visible cut, yellow gold cut fluorescence. 1 3/4'i Sandstone, fine-medium grained brown-grey, occasionally black, petroleum odor, good gold brown, good amber visible cut, yellow gold. cut fluorescence. 1 1/2" Sandstone as above, brown-grey, show as above. 1 1/2" Sandstone as above, show as above .~'~ ~ .... " 1~1/2" Sandstone, fine .grained brown-~..~y~;~ ~'h~w as abOVe. -5- 87. 5448' 1 1/2" Sandstone, fine-medium, as above, show as above. 88. 5436' 89. 54.28 ' 1 1/2" Sandstone as above, show as above. 1 1/2" Sandstone fine-medium grained, dark grey-brown, tr~ce clay matrix, fair porosity and permeability, show as above. 90. 5390' 1 1/2" Sandstone, very fine to fine grained medium grey, silty, friable, brown-gold fluorescence as above, bright milky white fluorescent cut, amber cut. 91. 5370' 92. 5358' Clay, buff to light grey, firm, massive clay, no show, contact to very silty dirty sandstone on edge of sample, show in sand as above. 1 1/2" sandstone, fine grained, well sorted, brown to dark gre: black color, brown gold fluorescent cut, as above. 93. 5351' 1/2" · Sandstone, very fine, silty and clayey, light grey-brow:-_ friable, uneven gold fluorescence, milky white cut fluorescence, light brown cut, very calcareous. 94. 5345' · 95. 5300' 1 1/4" Sandstone very fine t~ fine grained medium gre~ clayey, show as above, not calcareous. 1 1/4" Sandstone very fine-silty clayey, uneven dull gold fluorescence, not calcareous, cut as above. ....... '.96. 5288' 98. 4875' ·. 1 1/4" Sandstone very fine-silty, light grey-brown, clayey, ew but dull gold fluorescence., firm, slightl~ calcareous, Pale brown visible cut, milky white cut fluorescence.. 2" ~' ~:~' Sandstone, fine grained.b~9~D:.tO:.occasionally friable, poor to fair porosity and permeability, uneven gold fluorescence, cut as above, clayey, not calcareous. 2" ''Sandstone, very fine to medium (contact) and clay parting, medium brown, slightly calcareous, clayey, uneven gold fluorescence, milky white cut fluorescence. 99. 45~'~ 2" Sandstone, fine-medium grained, medium grey, soft and friable, clayey, dull gold fluorescence uneven non- calcareous, pale milky white cut fluor., no visible cut. 100.. 4520' 2" Sandstone as above, cut and fluorescence as above. · ...!01. 4208' "1 1/2" Conglomerate, medium to 6mm, very clayey, poorly sorted, heavy visible oil S'tain, uneven brown gold fluorescence, .::'~ ~ li~;~ t': ;'i ~'~:~ i? i'::~~p°°r porosity and permeability, tDoks wet. ~ !~ ~ ,, 102. 2 ii.. andstone, medium-coarse, grey, uneven heavy oil stain, ...ll..~i~ ~ ~; '~::'?~'~ '~ ..... '~layey, even dull brown fluorescence, poor porosity and .: ~' .' ' '~'"'" permeability, milky yellow cut. fluorescence, light ~IVISiON r:i: ~'~: ::,.qbrown cut. -6- 103. · 3970' 104. 3886' '105. 3876' 106. 3866' 107. 3858' 108. 3852' 109. 3801' 110.~ 3781' 111. 3770' 112. ~3760' 113, 3660' 1'14. 3640' 115. 3620' 116 ~ 3614 ' 117. 3606' 118. 3592' 119. 3588' 120. 3582' Sandstone, medium-coarse, fair sorting, medium grey, uneven dull yellow gold fluorescence, poor porosity and permeability (clayey) friable, non-calcareous, ~bright milky cut fluorescence, light brown visible. cut. 2" .' As at 4186' 2" As at 4186' 1 3/4" As at~4186' ,! As at 4186' Dt,.~.,.O,.~ r'~~, .".., Clay, medium grey, firm, very micaceous, sub fissile, no fluorescence, stain or cut, non-calcareous. 1 1/2" COnglomerate, pebble to 15 mm, grey, sand and clay matrix, no fluorescence, looks wet. 1/2" Conglomerate, granular to pebble to 8 mm, grey sand and clay matrix, dar~ brown, heavy oil stain, uneven , very dull yellow gold fluorescence. NR NR NR Sandston~ fine-medium medium grey, very friable, clayey. abundant heavy oil stain,'even brown gold fluorescence, non-calcareous, dark brown, visible cut, bright milky white cut fluorescence, 1,oo.k,s we~. 1 1/4" Conglomerate, Pebbles to 15mm, grey, sand and clay matrix, visible dark brown heavy oil stain, uneven brow~ gold.'fluorescence, looks.wet, cut and fluorescence, as above. NR 2" sandstone, fine-medium, clayey, abundant heavy oil stai~ uneven brown gold fluorescence, poor porosity and permeability, bright milky yellow cut fluorescence and dark brown cut. looks wet, non-calcareous. 2" Sandstone, as at 3606' 3/4" Sandstone, fine-medium, heavy oil saturation, even browr flUorescence, heavy brown cut, bright milky yellow cut fluorescence., wet? 1 3/4" Sandstone, fine-medium, same as at 3588' -7- 121. 122. 123. 124. 125. 126' 3575' 3504' 3348' 3150' 3140' 3136' 1 1/4" NR NR 11 2 t! Sandstone as at 3588' Sandstone, very nos-calcareous, milky white cut fine, friable, grey, slightly clayey, spotted dull yellow fluorescence, fluorescence, faint cut. Sandstone as above MiLE ,~,. NORTN RD. BOX 34 5 T.~ KENAI. ALASKA 99611 PH 19071 283-4403 CAMCO WIRELINE, ~NC. 7010 ARDMORE P. O. BOX 14484 HOUSTON. TEXAS MILE 4, NORTH RD. BOX 3453 "KENAI. ALASKA 99611 Ph. {907) 283-4403 Company. MOBILT-OIL CORPORATION Location P. O. BOX 4-1551 ANCHORAGE. ALASKA 99509 TELEPHONE {907) 272-5966 Well Borough KUPARAK 22-11-12 NORTH SLOPE Elev. 64 K.B. 45 G.L. Field .State_.._A_LASKA FormationSADLEROCHIT (9860-90,9910-356aie 19-21 MAY 1976 DATA DST # 2 CHRONOLOGICAL DATE TIME REMARKS ELAPSED GROSS TBG. SEPERATOR GAS GRAVITY TIME PROD PRESS TEMP. PRESS DIFF. VOLUME GOR ~ API HR.MIN BOPD PSIG o F PSIG 11.PI20 MCFPD * CFP @ 60° CUT % GAUGE #3637 T+ ~[~T BHP@ ([~T 9842 DPD. 19 MAY 1976 RAN 4000' WATER CUSHION INITIAL HYDROSTATIC 02:00 00:00 02:10 00:10 02:20 OPEN TO PIT ON 16/64" CHOKE 00:20 02:47 CHUSHION TO SURFACE 00:47 03:00 FLOWING 16/64" 01:00 03:22 .... 01:22 03:30 ." ,' 01:30 03:47CHANGED TO 01:47 24/64" CHOKE 03:50 GAS TO SURFACE 01:50 03:55 RAT HOLE MUD TO SURFACE 01:55 04:00 FLOWING 24/64" 02:00 04:12 MUD CUT OIL TO SURFACE 02:12 04:30 OIL STILL MUD CUT 02:30 05:00 FLOWING 24/64" 03:0© 05:15 TURNED THROUGH SEP. 03:15 05:30 FLOWING 24/64" 03:30 06: 00 .... 36: 30 " " 37: 00 .... D7: 30 .... 38: 00 .... 38:00 .... 39: 00 .... 39: 30 " " 10:00 .... 10: 30 .... 11:00 .... 10 140 200 300 400 500 500 510 510 510 650 650 04:00 04:30 1061 660 05-:00 1013 660 05:30 1056. 660 06:00 1022 660 06:30 1042 660 07:00 1022 660 07:30 1066 660 08:00 979 660 08:30 1080 660 09:00 965 660 650 650 994 650 78 8O 8O 8O 8O 8O 8O 80 82 82 81 81 4" X .75" COEFF.= 2714 315 33 278 311 210 89 377 395 210 89 377 413 220 89 385 367 220 89 385 379 220 89 385 372 220 89 385 377 220 88 382 359 220 87 380 389 220 86 378 350 220 85 376 390 20.7 23.9 24.5 24.4 24.6 10% MUD .6% .2% .1% .1% 4969 2299 2688 3O8O 3764 3757 3733 3760 3755 3571 3519 3478 3435 3381 3312 3309 3301 3298 3281 3274 3271 3262 3255 · 3250 3245 3240 3238 3229 -1- MILE 4, NORTH RD. BOX 3453 KENAI, ALASKA 99611 PH. (907) 283-4403 Com pony. MOBIL'- OIL CORPORATION ... KUPARAK 22-11-12 Location Field. P. O. BOX 4'1551 ANCHORAGE, ALASKA 99509 TELEPHONE (907) 272'5966 State__._~LASKA Borough NORTH. SLOPE Elev 64 K. B. -_ 45 G.L. _ FormationSADLEROCHIT(9860-90,9910L35~)ate 19-21 MAY 1976 DST #2 - CHRONOLOGICAL DATA DATE TIME ELAPSED GROSS TBG. SEPERATOR GAS GRAVITY _%,: 7. TIME PROD Pi:tESS TEMP. pREss DIFF. VOLUME G~ APZ REMARY.~J HR.MIN BOPD PSIG OF PSIG 11 I{20 MCFPD ,~CFP @ 60° CUT % GAUGE #3637 T+ ~T BHP@ ~[~T 9842 DPD 11:30 FLOWING 24/64" 09:30 1037 660 12:00 .... ~ 10:00 1022 660 12:30 .... 10:30 1013 660 13:00 .... 11:00 1008 660 13:30 COLL. GAS SAM- PLES #7875-L & 76018-K 11:30 1008 660 1.4:00 COLL. OIL SAM- PLES #1323 & #i326 12:00 1008 660 PUT WELL ON BY PASS TO PIT 15:00 FLOWING 24/64" CHOKE 13:00 15:45 CLOSED TOOL FOR BUILD UP 13:45' .; 82 220 85 82 '220 84 82 220 83 82 220 82 82 220 81 82 220 81 376 363 373 365 24.7 .1% 371 367 369 366 24.6 .1% 367 364 367 364 24.7 .1% 3223 3219 3217 3213 3209 3205 3195 3191 MILE 4. NORTH RD. BOX 3453 KENAI, ALASKA 99611 PH. (907) 283-4403 Company, MOBIL;'~OIL CORPORATION Well KUPARAK ..22-11-12 Borough NORTH SLOPE Elev. 64 K.B- 45 G.L. ATE 'IME REMARKS P, O, BOX 4-1551 ANCHORAGE. ALASKA 99509 TELEPHONE 1907) 272-5966 Location _Field Formatior~ADT,~,ROCHIT (9860-90,9910-35~ate 19-21 MAY 19_76 DST ~ 2 C H-R O N'O L O G I C A L D A T A GRAVITY API @ 60° CUT % ELAPSED GROSS TBG. SEPERATOR GAS . TIME PROD -'~RESS. TEMP. PRESS DIFF. VOLUME GOR HR.MIN BOPD~ PSIG ~F PSIG 11 H20 MCFPD *CFP GAUGE #3637 T+ ~ST ~,. BHP@ (fST,j-9842 DPD P~ODUCED APPROX. 600 BBLS. OIL *UNCORRECTED FOR GRAVITY OR COMPRESSABILITY AVERAGE RATE 1023 660 81 220 15:45 SHUT WELL IN 00:00 15:51 BUILD UP 00:06 15:57 " 00:12 16:03 " 00:18 16:09 " 00:24 16:15 " 00:30 16:21 " 00:36 16:33 " 00:48 16:45 " 01:00 17:00 " 01:15 17:15 " 01:30 17:30 " 01:45 17:45 " 02:00 18:15. " 02:30 18:45 " 03:00 19:45 " 04:00 20:45 " 05:00 21:45 " 06:00 22:45 " 07:00 23:45 " 08:00 20 MAY 1976 00:45 BUILD UP 09:00 01:45 " 10:00 02:45 " 11:~0 03:45 " 12:00 04:45 " 13:00 05:45 " 14:00 06:45 " 15:00 07:45 " 16:00 08:45 " 17:00 09:45 " 18:00 10:45 " 19:00 -3- 86 377 369 24.6 .1% 3191 138.5 4004 69.8 4066 46.8 4098 35.4 4120 28.5 4137 23.9 4151 18.2 4171 14.8 4187 12.0 4205 10.2 4216 8.86 4227 7.88 4234 6.50 4248 5.58 4259 4.44 4275 3.75 4288 3.29 4299 2.96 4306 2.72 4313 2.53 4318 2.38 4324 2.25 4327 2.15 4331 2.06 4334 1.98 4337 1.92 4340 1.86 4343 1.81 4345 1.76 4348 1.72 4351 MILE 4. NORTH RD. BOX :3453 KENAI, ALASKA 99611 PH. {907) 283-4403 Company. MOBIL'-OIL CORPORATION Well Borough DATE TIME REMARKS KUPARAK 22-11-12 NORTH SLOPE Elev. 64 K.B. 45 G.L. Location P. O. BOX 4"1551 ANCHORAGE. ALASKA 99509 TELEPHONE (907) 272-5966 'Field ..... State_. ALA,,SKA .FormationSADT;R, ROCHIT(9860-90,9910-35J)ate 19-21 MAY 1976 DATA DST # 2 CHRONOLOGICAL ELAPSED GROSS TBG. SEPERATOR GAS GRAVITY TIKE PROD PRESS TEMP. PRESS DIFF. VOLUME GaR .... .API MCFPD *CFP ~-~60° CUT % GAU GE #3637 T+ ~>T BHPCa ~T 9842 DPE HR.MIN BOPD PSIG °F PSIG 11 H20 -- . 11:45 BUILD UP CONTD. 20:00 12:00 " 20:15 20 MAY 1976 12:00 OPENED TOOLS 8/64" 00:00 12:06 CONDITIONING'FOR SAMPLE 00:06 12:12 CONDITIONING ON 8/64" 00:12 12:24 " 00:24 12:36 " 00:36 12:48 " 00:48 13:00 " 01:00 13:15 " 01:15 13:35 CHANGED TO 6/64" CHOKE 01':35 13:45 CONDITIONING ON 6/64" CHOKE 01:45 14:00 " 02:00 14:15 " 02:15 14:30 " 02:30 14:49 CHANGED TO 7/64" CHOKE 02:49 15:00 CONDITIONING ON 7/64" CHOKE 03:00 15:15 " 03:15 15:30 " 03:30 15:45 " 03~45 15:50 CLOCK RAN OUT 03:50 17:00 CONDITIONING ON 7/64" CHOKE 05:00 18:00 " 06:00 19:00 " 07:00 20:'00 " 08:00 21:00 " 09:00 22:00 " 10:00 75 150 80O 925 1075 1200 1250 1300 1325 1350 1275 1~75 1200 1200 1250 1275 1260 1260 1.69 4354 1.68 4358 2351 2598 3260 3914 4045 4086 4115 4132 4199 4223 4235 4244 4251 4237 4239 4213 4220 4227 MILE 4, NORTh RD. BOX 3453 KENAI, ALASKA 99611 PH. {9071 283'4403 Compa'ny MOBILTiOIL CORPORATION Well Borough KUPARAK 22-11-12 NORTH SLOPE Elev. ~64 K.B. 45 G.L. Location :. Field_ P. O, BOX 4-1551 ANCHORAGE. ALASKA 99509 TELEPHONE {907) 272'5966" __State FormationSADLEROCHIT(9860-90,9910-35jDate 19-21 MAY ]976 ._ DST 02 CHRONOLOGICAL D-A TA DATE TIME ELAPSED GROSS TBG. SEPERATOR GAS TIME PROD PRESS TEMP. PRESS D!FF;~':~vO~uME GOR HR.MIN BOPD PSIG °F PSIG ~ MCFPD *CFP GRAVITY API @ 60° CUT % GAUGE #3637 T+ bT BHP@ ~T 9842 DPE 23:00 CONDITIONING ON 7/64" CHOKE 11:00 24:00 CLOSED TOOL AND TRAPPED SAMPLE 12'~00 1260 12~o0 ATTEMPT TO MEASURE RATE THROUGH SEPERATOR WAS UNSUCESSFUL, AS RATE WAS TOO LOW FOR 1" TURBINE METER EST. RATE = 150-200 BOPD. 21 MAY 1976 14:00 PRESSURED UP WITH Hg PUMP ON DCIP SAMPLER 19:00 AND PUT GAS BACK IN SOLUTION THEN TRANSFERRED TWO 625 c.c. SAMPLES @ 5,000 PSIG TO STEEL SHIPPING BOTTLES, NOS. 1335 AND 1709. 2 10 10 1 · , T+A.T ' ~ ' Ol (:~11 I I I I I I I A.T . '¥'$'n N~ 3aV~l "OD MILE 4. NORTH RD. BOX 3453 KENAI. ALASKA 99611 PH. (907) 283-4403 Company. MOBIL OIL CORPORATION Location P. O. BOX 4'1551 ANCHORAGE. ALASKA 99509 TELEPHONE 1907) 272'5966 Well KUPARAK.22-11-12 Field. State_.ALASKA Borough NORTH SLOPE Formotion~ADLEROCHIT(9860-90,9910-35Date 19-21 MAY 1976 _ SUMMARY PRODUCED A TOTAL OF APPROX. 600 BBLS OIL 24.7° API PRODUCED WELL FOR 13.75 HRS. RATE 1023 BOPD 367 MCFPD 364-1 GOR BHP 3191 P* = 4385 VISCOSITY = 1.0 cp (Est.) FVF = 1.25 (Est.) -6 TOTAL COMPRESS. = 11 X 10 (Est.) POROSITY = .15 (Est.) WELL BORE = 8 in. SLOPE = 170 PSI/CYCLE Kh = (162.6) (1023)(1)(1.25) = 1223 Md ft./55 ft. K = 22 Md. 170 SKIN = 170 X .87 X -2.15 = -318 PSI =/-00105 (22) (13.75) V~' (.15) (1) (11 X 10-6) = 446 ft. =. 1023 = 0 857 BOPD/PSI DRAWDOWN P.I. 4385-3191 ' GAUGE # 3647 DEPTH_ 9812 INITIAL HYDROSTATIC 4882 INITIAL FLOW 2~17 FINAL FLOW 3~79 : CLOSED IN 4~61 INITIAL FLOW 2205 FINAL FLOW 4234 ~3646 9817 4886 2241 3189 4363 2252 4228 3637 9842 4909 2299 3191 4358 2300 4226 3636 9846 4887 2325 3224 4379 2379 4271 i ' / ' SA,%i I'L I'-' DATA · / O~zrater~OBII. C)TT. CO.OPTION Lease and %VcB No ~icld. Count~, State, Country. NORTH SLOPE t ~AS~ KUPARAK 22-11-12. ' Separator Pressure Sample- container Data Container No. Date (Eomplct~ this sect;o, ,vhcn .SURF~ICE S,.,.. LIAG method 220 (psig) Separator Temperature 81 · , . ... luid ,. ' 1323 1326 7 8;/5-L 5-19-76' 5-19-76 5-19-76 13: 45 14: 0'0 13: 30 · 15 ]'5 15 15 Time Atmospheric Temperature (F) Gas 1-76018-K' 5-19-76 13:40 Drier Uecd '](es - 1%1o X ',.- X .__ X X ._ -~ / ~ow~asoutage ...... ~,~=,, :_ ~:_..:z,,, ,*~-'~, ~-,,,,,,,~-~"~-'~FILLED 675 Cc. BOTTLES .WITH 625 cc. OIL THEN BLED Gas-sampling' ~ethod EVACUATED .CYLINDE~ · . Liquid-sampllng iVIethod DISPLACING WATER Sampling Data (Complete this section when SUBSUt~F,dCE S~dMPLING method is used) Container No. Date Well Sampled Time Well Sampled ~NeI1 Shut-in Time (hours) G~s-eiI Contact (ft) Oil-water Contact Sn_mpTdng Depth {ft) Sampling Depth Pressure (psig) Tubir~ Pressure (psig) . Casing Pressure (psig) Smmpler Pressure after Valve Opening..(pslg) Sample Transfer Temperature Sample Transfer Pressure (psig) · Sample Shipping Pressure (psig.) Outage Taken in Sample Container (cc) Container Volume (cc) ~Remarks: Sample No. 1 1335 - 20 MAY 1976 24:00 · -.- '.FLOWING' 150-200 BOPD · . 9801 4225 1260 1800 50' 5000 25 cc. 670 cc. Sample No. 2 1709 20 MAY 1976 24:00 ___ 9801 4225 1260 1800 50 5000 25 cc. 660 cc. · SAMPI.E TAKEN @ 220° F Sampled by CAMCO, INC% - STEVE REYBURN _Data prepared by, STEVE REYBIJRN o · .. . . °' . . . REST OF H-20. · ~COMPANY 0 L OIL COP~. ~~i~. i~-~u,~o,,,,,~... ~ST~!,~~~-i°~'V~-~-~-'-~'~'~'~-~....~... ~" ' L S E .............. 0 ~ __ PR[~DHOE BAY ....... t: ,, MILE 4. NORTH RID. BOX 3453 KENAI, ALASKA 99611 PH {907) 283~4403 CAMCO WIRELINE, INC. 7010 ARDMORE P. O. BOX 14484 HOUSTON, TEXAS 77021 DATE TIME MiLE 4, NOrTh rD. BOX 3453 KENA}, ALASKA 99611 Ph. (907) 283-4403 Company. MOBIL OIL CORPORATION Well KAPURAK 22-11-12 P. O. 8OX 4'1551 ANCHORAGE, ALASKA 99509 TELEPHONE (907) 272-5966 Borodgh NORTH SLOPE Location 00:10 00:20 00:30 .... 00:40 " " 00:48 .... 01: 00 .... 01: 10 .... 01:20 .... 01: 30 " " 01:40 .... 01:50 " " 02:00 " " 02:10 " " 02:20 " " 02:27 " " Fie'Id .State ALASKA 02:27 02:28 02:29 02:30 02:31 -02:32 02:33 02:35 02:37 02:39 02:41 02:43 02:45 02:47 02:52 02:57 03:02 03:07 03:17 Formation SADLEROCHIT (934-35) .. Date 17 MAY 1976 DST #1 (W.S.O.) , C H 'R O N 0 L O G I C A L .D A T A . GAUGE · GAUGE GAUGE #3637 _;'!/ .. ELAPSED BHP@ / TIME T+ bT D P.D REMARKS MINS. OT '~ 9842 K.B. BHP@ BHP@ BHP@ D.P.D. D.P.D. D.P.D. 9847 K.B. 9873 K.B. 9877 K.B, 17 MAY 1976 4000' WATER CUSHION INITIAL HYDROSTATIC OPENED TOOL 4000' WATER CUSHION TOOL OPEN 0 10 2O 30 38 5O 60 70 8O 90 100 110 120 130 137 5023 3623 5023 5040 5048 1605 1749 1890 2005 2100 2287 2447 2609 2754 2891 3002 3136 3267 3498 3623 3633 3647 SHUT TOOL IN BUILD UP I! l! I! l! Il l! Ii Il Ii 0 1 2 3 4 5 6 8 10 12 14 16 18 20 25 . 30. 35 4O 50' 138.0 '69.5 46.7 35.3 28.4 23.8 18.1 14.7 12.4 10.8 9.56 8.61 7.85 ':6.48 ,5.57 4.91 · . 4.43 3.74' 4069 4202 4244 4266 4282 4292 4306 4317 4325 4331 4336 4341 4344 4351 4356 4360 4363 4370 MILE 4, NORTH RD. BOX 3453 KENAI, ALASKA 99671 PH. (907) 283'4403 Company:. MOBIL OIL CORPORATION Location P. O. BOX 4"1551 ANCHORAGE. ALASKA 99509 TELEPHONE (907) 272'5966 Well KAPURAK 22-11-12 Fie'id .State___ALASKA Borough 'NORTH SLOPE Formation SADLEROCHIT (934-35) DST #1 (W.S.O.) CHRONOLOGICAL DATA GAUGE Date 17 MAY 1976 GAUGE GAUGE ~3637 DATE TIME 03:27 03:37 03:45 REMARKS J ELAPSED 'TIME ' MINS. BUILD UP CONT'D i! . PULLED RTTS LOOSE BHP@ BHP@ BHP@ BHP@ T+ ~[~T D.P.D. D.P.D. D.P.D. D.P.D. C'~T .~9842 K.B. 9847 K.B. 9873 K.B..9877 K.]~ 60 3.28 4374 70 2.96 4377 78 2.76 4380 FINAL HYDROSTATIC 4936 4937 4964 4958 7" #CSG. 3%" 9.3 #TBG. 4000' WATER.CUSHION REVERSED OUT FROM DRILL PIPE 38 BBLS. FROTHY MUD CUT OIL PLUS 3 BBLS RAT HOLE. - J. Reversing Sub ..................... Water Cushion Valve ................. Drill Pipe ........................ Drill Collars ...................... · . .. Handling Sub & Choke Assembly ....... Dual CIP Valve ................... Dual CIP Sampler ..... ' ............. Hydro-Spring Tester .............. '.. Multiple CIP Sampler ................ Extension Joint AP Running Case ' i. Hydraulic Jar ..................... YR Safety Join~ ............... ~_..~ ~ Pressure Eq,,alizing Crossover ......... DistributOr Packer Assembly .............. . ..... Flush Joint Anchor .................. '. Pressure Equalizing Tube ............. Blanked-Off B.T. Running Case ...... ; Drill Collars ....................... Anchor Pipe Safety Joint ............ · . Packer Assembly ' · . o . Packer Assembly . · . Anchor Pipe Safety Joint Side Wall Anchor ............ ; ...... /, . O. D. ' i' Jo D. 2.3 , . . ! Drill Collars ...................... Flush Joint Anchor ................. Blanked-Off B.T. Running Casa ........ I LENGTH 3,?? : i~t'~l llPh/li:'lklT r'IATA DEPTH o.. · i 7Y LITTLIK'I IS?e3 2 10 10 1 '¥'S'N NI 3Q¥i~1 '0~ ~J~SS'=l ~ T:l_-I_-In~l~ i~Z61~ 917 s~o,s,^,a 0L × S:I'I:DA3 ~. :DIIAIHJ. I~IY90-I-II~I:I$ ~----~N · . hipstcck A PETROLANE COMPANY REPORT of SU~-.~URF,~CE SURVEY Mobil 0it Corp. COMPANY Kupar'sX 22-11-12 WELL NAME North Slope LOCATION JOB NUMBER A_576 G01 20 SURVEY BY Shyam 'Talwar TYPE OF SURVEY ;/L/~, ;~. DATE ~r~-scop~,~ ? ~.:. ii r,..~ ~-~-7~ OFFICE Alaska -~OMPLgTION REPORT ....................... -.. _MOBIL- OIL CORP, .............. .... GYROSCOPIC SURVEY __RADIUS OF CURVATURE METHOD OF COFiPUTATIONS CO?.~UTED FOR EASTMAN WHIPSTOCK' INC, BY F, MAY -18,],976 KUPARUK 22=11-12. KB ELEV, 63 FT, M, LINDSEY AND ASSOC, RECORD OF ALL CAI..CULATIONS PERFOR;'4EU BY SURVEY . B v~ ELECTRONIC COMPUTER .... TRUE """ E' m T H ANGLE DEPTH SUB SEA DRIFT DIREC DEG. -fr.) T A L ...................................... DOG LEG. ................................... )_ COORDINATE5 C L O $ U R E .5 SEVER'ITY SECT~.~W, DISTANCE ANGLE DEG/iOOFT DISTANC[ ..... C 0 0 0 · ""..' 0 .............. t.)u 0 0 iOt),OO 200 O. 2500 O 30 29~.99 403 0 29 399.99 500 C; 15 ~99.99 .......... 600 0 g~' .., . ~ 5qc.99 ,~,O 0 Z5 699,98 403 O lO 799,'38 llJC d 5U 1099,97 _. 1200 I 0 11~9.96 i';03.. ~" ~.~O 1299.95 .... i&O~ 0 .__ i~3S 0 2O ~600 ~ ~ 1599,9a .... 1700 0 15 1699,54 .... lo00 0 gO 1799,94 _. 1900 0 30 1.>q9.93 20 C"~ C 50 ~.~';t, a5 2C9o 9~ _ 223C 0 30 2iP9.91 ___ ~.. O 5v 2299,91 · 2433 i 0 2399.S9 -63,00 37,00 137,00 2'26,99~ 336,99 436,99 536,99 63&.98 736.98 836.98 93G.gu lO36,97 1136,96 1236.95 i336.95 ~436,9~ 1536,94 ]636,94 1736,94 1836.93 1936,93 2036,92 21~6,91 2236,91 2336.~9 0 · 0 0 0.39 0..~i 1.1~ 1 · 64 O. 92 0.49 0.53 O, fa 3,2'7 4,49 ~,25 4.I.D 2.b~ 2.60 3.i6 5,37 S S S S S S S S S S S S S S S S S S S S S S S 0,00 C,UG · O~O0 0,19 0,75 1,05 1,59 2,01 1 · 72 1 1,54 1.51 1,75 ..... 1.38 0,53 0,22 0,~6 O, 14 ...... 1,Z6 ..... 2,31 3,63 a. 6'2' 6,20 _.. W O,O0 W u.OO E O,a3 1.1]. E .... i,58 E 2.29 E ......... 2.22: E 1.Y9 E 1,69 E ! .71 . . . E 2 . E 3 · 71 E_ . _ 4.59 5 E 4,87 S vi 4.58 S W ~,27 S W_ 4,10 5 E 3,56 E ..- 3,34 E . 3,46 E ~.59 E .... 6,-/~ E 8 ,.20 S 0 S u S S 25 $ 42 S ~+1 S S 65 S 73 S 71 S 64 S .1 S 28 17 0 0 u 0 0 0 5-9 ~9 55 30 £ Z3 2 g ._ O,OCO W OeOO0 .. 0.00. E Q,~O0 .................... -0,33.. E 0,160 ...................... -1,O2 .0,090 .............. -1-~4 0,'20 ....... -2-12 O,z4O ................... -2,22... 54 48 E 39 10 E 22 19 E 58 ~+u i 11 6 E 19 6 E 0,260 ...... -1,77 0,170 ........... -1-68 0,250 -1,7l 0-590 ........... - ~6. O,15O -- . -~-~2 O,DOO ................. 0,090 ..........-2-43 2 ~7 40 4 54 0 2 1 33 S 8 21 ~Z S 22 15 Z5 S 41 49 3 S 54 41 46 S 5b 31 32 S ~;~ 42 ~7 S 49 5 17 0.250 ......... -1,65 0.250 ..................... 0.150 ......... -l-SJ 0.420 .......... 2-06 0.170 ................... -2-4i O,~aO ........... 0.090 - -~.-42 0.'250 ............ -.5,49 0.340 -6,50 0.160 -.- -7-8~ i¥iEAS. DJ-? !FT _.~.P P TH_ .A,,GLE ..... 250.O _ 260O 2700 2900 .... 30 O 0 3100 .... 3400 ..... 3500 __ ~ 700 39OO _.4~00 4500 4700 ~600 .... 4900 __. 5000 __5100 5200 : 5300 ........ ALL CALCULATIONS P'ERFOR?,tED B.Y TRUE VERTICAL SUB ._. DEPTH SEA D M 1 0 1 30 1 15 1 0 0 5O 1 0 2 3O 8 15 13 0 14 45 15 0 16 4.5 1 8 20 gO 40 21 45 25 30 32 45 37 ~0 ,~6 0 3O 0 15 39 20 2O 0 15_ 2499,88 2599,85 2699,82 2799,80 28P9.79 29~9,78 31g9,25 3297.51 3394.5~ 3491.23 35~7.41 36~2,85 3777.40 3B71.16 3964.39 4055,63 4i43,70 ~2~9.07 A313.W'6 4395.71 4~76.35 4555,55 4633.4.0 4712.20 4~52.bo 5041,36 2436.88 2536,85 2636,82 2736.80 2836.79 2q36.7~ 3()56.73 3136.25 ~234.51 ~331,58 3428.23 3524,41 3~19,85 3714~a0 ~838,16 3901,39 3992.63 4060.70 4250,06 4332,71 4413,35 ~492,55 4570,40 46~9,20 4M12,85 4895,58 4978,36 RECORD OF 5URVEY I ~ M ELECTRONIC. ¢Oi','!PUTEk .. D~&IFT DIREC DEG. S10.00E N45.0OW NS0.3uw N62.OOW N 6 8 · ¢) 0 w N 7 a · 00 W N~iS.0Ow I~ 74 · 00 W Ng O · N78,OOW N76.OOa N74.(')OW N78..oUW N76.00W I"182.00~ N77.00W H85o0C~ N~4.00W N82 ,O",_, ~." N83 · 0 OW N b 2 · 00 ~'; N85.00~ FITO.OOW Nbg.00W DOG TOTAL COORDIi~ATE.$ .... C L O S U R E S SEVERITY .............. ~EC. TION DISTANCE ......... ANGLE ............... DEG/iOOFI ............ ~I,STAN~ 7,08 7,84 5.04 4.21 3.54 2.54 2,51 7,90 12.o0 18.9~ 26.6g 34.55 02.37 49.27 57.06 68.il 86.20 89.21 94.60 101.31 111.36 1gl.l~ 128.15 13~,2J 146,G9 164.77 184,42 S ......... 6.53 E ............. S 5,07 S 3,30 E S ......... 1,74 E .............. 0.36 E 1,08 W 3,97 13.16 W 31,26 W 54,61W 79,81W i06,46 W 13~,30 W 166.89 W 200,74 W 236.24 W .~ 276.33 W 322.35 W. ~72.97 W .... 426,4~ W .. 482,~7 W .b41,15 W ..... 601,45 W . 563,43 W D M 9,64 S 42 40 9,34 S 32 54 7.05 S 27 28 5 g 0,510 ......... 7.82. 57 E 0.250 .... -5,5a 5.33 S 19 2 16 E ....... 0.250 4e23 S 4 56 58 E 0.160 3,70 S 17 5 5B ~ 0,160 4,72 S D7 21 7 ~ . 1,500 ........ : ........... 2-60 13.19 S 36 ZOI 9 W 5.754 .................. 11,59 31,36 N 85 24 30 55,18 N 81 ~6 2 ~0,83 N 80 53 19 108.14 N 79 54 21 137,91 N 78 50 41 170,43 N 7~ 18 6 W 205.17 Iq 78 4 53 W 241,33 t~ 78 13 8 W 282.16 N 78 19 55 W 32~.47 N 78 4 8 w 5Ui,Di N 77 ~£ 17 W 43b,~8 N 78 11 2 ~ 491,66 N 78 54 19 W 550,65 N 79 20 41W ..... 1,66~ 611.67 i~ 79 30 ~5 W 674.41N 79 ~8 54 w 58 13 W .. i5 57 ~ 4 54 W. 9U6,00 N 79 $1 16 W 961,2~ N 78 56 21W N. 724.59 W ...... 735.83 N 79 .._ ~37,79 W ._ 850.50 N ~0 890,89 _943,44 W. _ 4,783 ..... 29,60 W 1.793 .................... 53,13 W 0,284 75,15 ~ ....... 1,26~ ................. 134,51 2.05~ 166,58 0,715 .... 200.70 3.509 32~-'3i 2.766 ]73-5i. 2.6~1 .......... 2.52~ .... 1,466 .... 594',99 1,~B9 655.64 1.867 .............. 769.80 0.712 ............ 881*ga 0.40~ ........... 9~7-26 RECORD OF ................................ ALL. £ALCULATION$ PERFOR,MED BY TRUE 'i."~'i"E-JA$, D~]~T VERTICAL .SUB .... DEPTH ANGLE DEPTH SEA DRIFT DIFEC _:..~5400 34 0 5124,15 5500 34 10 5205,97 _. 5600 34 O 52~9.79 ..... 570o 5800 32 15 5~56,92 5900 33 0 5541, .... 6000 31 20 5525,7~ 6100 31 0 5711,35 __ 6200 30 30 5797,29 .... _.. 8300 .29 50 5~83,74 6aO0 Z5 20 597~,35 6500 -- 6600 .3 O 6155,~0 6700 23 50 6247.N6 6~09 23 30 6339,1a .... 690O 23 7000 22 15 6922.~8 7200 25 &5 6705,67 ..... 7~00 __7500 30 O. 6975.n7 __7600 33 0 7060.72 7700 ~A 0 71A~,11 7809 ~5 15 7226.~0 79~C' 36 O 7307,6B ~000 ~6 0 73~8,5~ 8100 ~z~ ~5 7~70.12 b061,15' 5143,97 5226,79 5393,92 5a7b,14 55(52.78 564~8 '35 5734,29 bB20,7a 590'9,35 6O0O · 60 6U92 · BO 6184.56 62~6,14 6367.8~ 6551.95 ~733.47 &912,47 699-{.72 7163.fl0 73~5,b8 740'I · 12 74~9.4~ SURVEY I b ~,'~ ELECTRONIC .. COi'4PUTER · DOG LEG S U R F_ S . . SEVERITY ..... SECTION .... ANO L k' .......... DEG / 10 O F.I ............... D.i ...... D M S ................................ 995,81 W 1016,60 N 78 23 3b'W - 0.250 .................. 993 )- 1048,47 W 1072,07 N 77 57 Z2 W 0,653 1100,96 W 1127,52 N 77 32 15 W 0.953 .... 1105,13- 1152,2B W .... 1182,27 N 77 4 .6 W ..... 0.585 ..............llaO,-~-g 12Ok.Z5 W 1235.75 N 76 37 42 W 1.250 ..............1214.95~ lZ52.G6 W 12~9.01 N 76 i4 53 W O.a07 ....... 1268,a4.- 13.01,92 W 1341,89 N 75 55 51 W ....... 1.84~ ................ 1321,9~..~ 1350,06 W 139~,21 N 75 ~2 14 w 1,'S69 1)7~,~.~ 1396,59 W 1~45,56 N 75 20 40 ~' ..... 0,562 .1485,29 W 15B9,09 N 74 48 ~4 w a,51~ 1523,54 W 1579,66 N 7~ 40 58 W 2.853 15~1.96 1561,00 W 161~,53 N 7~ 40 43 W 0.~93 1599,30 W 1658.27 N 74 40 2'[ W 0,855 . 1639,7%. 1631,89 W 1698.~2 N 74 D9 ~0 W 0,340 ....... 1579.50 1675.81 W. _.. 1738.24 N 74 35 50 ~ .... 1,595 ........ 1719,1~- 1711,97 W i776.89 r~ 74 27 51 W 1,322 175 ~9. 1747,99 W 1815, (9 N 74 17 33 W 1.758. 1786.26 W 1B57.37 N 74 5 39 W ......... 1,-ia0 ......... 1E24,05 W 1e95.66 N 7~ 53 i w ~.007 ....... 1862,88 W .- 1940,44 N 73 44 44 W 2,621 ......... 1923,19 1~C7,~8 W 1~67,3~ N 73 45 6 W ...... a,272 ..... 1969,6~. 1959,08 W 2039,46 N 73 51 37 W .-3,058. - .... 2020e78 2012,73 W 20~4.58 N 73 P~ 47 ~ . -- 1.856 2065,91 W .2151.~7 N 73 53 32 w .... 1,600 ......... 2131e5t-- 2121,65 W.. 2209.49 N 73 47 22 W 1.320 2169,62 2175,53 W _2267.79 N 73 36 4 W 2,938 2Z~8,36 666,52 i't. g227,11 W ......232'~,71 N 73 20 19 W .... 1,~09 693,03 N. 2277.05 W .... 2380,35 N 7~ 3 29 W 0,407 - - 2302,82 .......... . . . .... ...... , TOTAL COORDINAT'E5 C L O ...................................... D I STANCE 20a,52 N 223,69 N 245'31 iq 264,57 285,75 306.al 32b,00 ~4,U2 365.22 385,20 40~,3b q17,2~3 ~27.66 ~38.2Y 449,~5 461.67 475,~2 50~.U2 527,bg 543,13 556,06 5~6,T2 579,80 596.gE 640.24 .............. RECORD OF ....................... ALL CALCULATIONS PERFORMFD BY TRUE _Y, EA$,' DRIFT VERT :[(:AL _DEPTH A?qSLE DEPTH SUB DRIFT SEA DIREC DEG, SURVEY I ~3 ;..'~ ELECTRONIC.'COMPUTER ............... DOG LEG ............................... TOTAL COORDINATES .......... C L O $ U R E 5 SEVERITY ....... SECT[ON- ...................... DISTANCE, .... ANGLE DEG/ZOOFT ......... D :[,STANCE D ..... 53')0 ., z,,.0 '/'6~ 5. O? 7,572.07 N61.00W 8,q. t:, 0 3z+ 0 7717.97 7654.97 N 59 · (.)O'¥v 8 = "" '"' . N ~,v 3B 50 7800,a5 7737.95 54.00W .... ~o',;~.,33 30 7~:~° ,. ' . .... . ...4,18 7U21.I*~ I'460,00W ¢700 qz, 5r', 7966.91 7903,91 N63,00W . .. -. ~ k..~ ....... EgC.,034 3rd x, 131.B2 oO6~,32 9COt' · -~ ~4 15 ~2~3,d6~ 8150,86 .... qfC3 35 0 ~.296,15 8233,15 N55.00W 92C'~ 3A z.~ ~'~'7~,19 8.3!~,19 N53o0U',4 043C. '~a ~ o~,41.21 ~f~Vq.21 6~""~()~. 3¢,.. ,~m, a7C'~c6,,, S6~Z~¢~6. , .... :9.~03 34 33 2S5U,1~ ~E05.18 h37,O0W ............. 2~,72 qpc:7,?2 36,0C _IC:¢'a.?¢ 3', 3 9~66,4q 9(~03,49 r.:B5 _.. !~ ic;2 34 ('. 9192,51 9129,51 720,91 779,06 809 · 34 836 -64 906,75 936.~iq 970.48 1006,52 1003.69 112.5 · 40 11oo.67 1213,i6 125a.55 1~21.35 1391.:;. 1 66 5 a6 N 2326 · 27 W N 2374,70 W N 2421,21 W N .2467,69 W N 2517,04 W N 2.968,95 W :",i 1621,45 W N 2672.17 W N 2720 · 33 W N 2766,59 W hi 2~1,59 W N 2~55,63 W 5: 2696.89 W ,',~ 2937.22 W N 2970.St W N S012 . ~ 7 W . N 3645 · 76 W ~': 3C91.87 W N 3140.62 ~ 2435,42 N Z4W9,98 N 2543,65 N 259'7,18 N 2652,45 N 2709,17 N 2765.66 N 282t,83 N 2877.i4 N 2931.87 IN 2956.61 N 3040,07 N 72 g6 53 ~ 72 29 49 W 72 9 2 W 71 49 52 ~ 71 56 49 W 71 29 6 71 24 12 W .. 71 15 20 70 59 ~6 70 40 il 70 18 1~ 69 54 ~0 ~0.92.95 N 69 29 23 3145,46 N 69 2 4 5197.~! N 08 3~ 31 3247.30 N 68 ~ 45 5295,5a t4 67 32 56 3343,63 N 67 2 39 ~362, /5 ?~ 56 50 39 3935,27 i'~ 66 5 0.500 ....... 2416 t,118 247~,47. 1,559 - - 2529,48. 1,660 ....... 2640o17 1,627 ...... 2097.22 0.407 ............ 2754,02. 1,917 2B10,42 2,112 28o6,64 0,695 2922,55. 1,624 - 2978-5~ 1,351 1.021 ......... 3007.5a 2.121 31~i.34 i,~3~ 3194,~a W ..... 1.377 ..............32a5.~ 0.~0~ 3Z~ ~9 l.O01 ............. 3362.49 O.O00 3%35.27 _2fiEASURED_DEPTH AND OTHER DATA FOR EVERY .............. TRUE FEASURED ..... VERTICAL_ SUB DEPTH DEPTH ........... 163 .. '163, ...... 263 263, 363 ........................ 363, ......................... 463 463, ............ 563 .. 563, 663 ...... 663. 763 763. ~63 863. 963 963, 363 1063, 167 1163. 263 1263. 3.63 1363, 463 1463, 563 ....... !563, 663 1663, -'6 O53 063 163 263 363 2563 2763 2F&3 2mA3 3G53 3~65 3367 3471 3575 1763 1863 1963 22'63 2163 2253 2363 2a53 2563 2563 2'763 28.63 2963 _ . . 3163 3263 336,3 . 3463 ......... 3563 M D-T VL) SEA DIFFERENCE 100 0 200 9 300 0 400 0 500 0 600 0 700 · 0 860 0 9O0 0 lOOC 0 1!00 0 1200 0 1300 0 1400 0 1DO0 1600 0 1700 0 .i,~00 0 1900 0 2000 0 2100 0 2200 0 2300 C 2aOo 0 2509 0 2600 27OO 0 2800 0 2900 0 3000 0 3100 0 3200 1 .., v 0 4 3a00 7 3500 11 EVL,N CUP, RECT I©N 100 FEEl' OF-SUB SEA DEPTt.t. ......................................................... · VERT I CAL .................................... · TOTAL COORDINATES .................................... 0 ......... r.L.;,r..;O S (.},00 W ' 0 ........................ Co15 S 0,07 E .....................................~ ........... 0 ....................................... 0,74 S 0,52 E 0 .............. 1,00 S 1,02 E .......................................... 0 ...... 1,52 S 1,26 E 0 ...................... ].,89 $ 2,15 0 U.60 $ ~,B3 E 0 ~,~+~ S 1.60 0 .................... 0.6t S 1,58 E C i. Z1 S 1,~9 E ..................... O. 2,64 $ 1,6~ E C ......... 4-.17 $ 1.61 E 0 . . z,.79 S 0,90 E 0 4.70 S 0,00 W .............................................. 0 ............................. 4,35 S 0.~8 W -. 0 4,14 S 0,27 ~ ............................ 0 ...... 4,03 S 0.25 E ........... 0 ...................... 3,31 S 1,00 g ............................................. 0 '. 2,75 S 1,8~ 0 2.51 S 3.19 0 .................... 2,92 0 3,63 0 4,78 0 6,4b 0 ~,0i 0 6.77 0 ....... 5,43 0 a,49 0 ............ 3,79 0 ............ 2,98 0 ........ 1.51 1 ............. 0,79 3 .......................... o, 31 3 ......... 11.25 4 ......... '1'7,23 4.34 E ................................................... 5.07 E ................ 5.99 E ................ 6,41 E ........................... 5.85 E .................. 3.94 E ............. 2,29 E ................................. 0.85 E ....... 0,50 ~ ........... 2,51 W .................... 8.5i ~ ........... 24.03 W . ............. 4b.53 w ................... 72.4'2 W ...... 99,42 W ......... M ED --~.t. EASUR DEPTH AND OTHER ................. TRUE ............ !'!EASURED ..VERTICAL ...... DEPTH DEPI'H ............ 3679 3663. 37e5 3763. 3891 3863, 3998 396B, z. 222 416B, ........... ~4.0 4263. ........... A460 ................... 48~8 ~663, 5326 ....... 506~. ............. 5aa7 5163, 5568 5263, ~588 ........ 5363. ..............5807 5463, · 5926 5563. 6~50 5763. 6276 5863 6390 5963, 6499 6063. ......... 6608 .. 6163. 6717 6263, ....... 6~26 6363, 69~5 6455 · 7'2a3 6563 · 715~ 6563. .~_ 7373 ..... 74~6 6963, ........... 7503 7063. DATA FOR EVERY EVEN SUB MD-TVD SEA-DIFFERLNQE 3600 16 3700 21 3800 28 3900 35 4000 45 4100 59 4200 °77 4300 97 4400 120 4500 146 4600 175 4700 200 4800 '221 4900 242 5000 263 5100 2~3 5200 305 5300 325 5400 344 5500 363 5600 380 5700 397 5800 413 5~00 427 6000 436 6100 6200 a54 6390 463 6500 480 6600 489 67E0 530 65O0 510 6900 522 7O00 539 100 FEET OF-SUB SEA DEPTH, · VERT ! CAL CORRECTION TOTAL 5 .... 24,93 7 .......................... 41,61 7 49,15 10 .......... 57.9~ 14 ..................................... 70.63 18 ...... 84,83 ZO . 92.29 23 .................................. 100,4~ 26 ....... 112,32 29 .... 12~.27 25 ................................. 1~1,76 21 14~o84 21 ....... 165.73 21 189,66 20 .... 213,73 22 236,68 '20 .........................251.99 19 287,24 19 311,60 17 ....................... 332,72 17 356,68 16 380,71 14 .......... 401.5~ 9 _ 417,16 8 42~ · 45 10 .................. 440,16 9 ........ ~52,B0 9 _ 466.52 8 .......... 452.44 9 500.56 11 ..... 52~.~5 lO .................. 539.11 17 554.38 .......... 17 _ __ 567,20. N COORDINATES ...... . 129.10 161,~1 197,66 235,~1 279,82 394.15 W ' 459,65 W ............................ 531.05 W 606.94 W ........................... 687.13 W 761.25 W 829,15 W 893,52 W . 957.09 W 1020.39 w 1084,12 W 1146.18 W ..................... 1205,69 W 1265.1~ W 1322.88 W ........................... 1378,10 W 14~1,50 1481,19 W 1523,16 1563.96 W 1605,85 W 16~7,83 W 1688.76 1727.15 W 1767.92 1~10,44 W 1851.~9 W 1901.08 w 1960.53 ~'/~-$'()"~EIJ)' DEPTH .'AND"~OTHER' DATA FOR TRUE EVERY EVEN SUB MD-TVD SEA DIFFERENCE 23 7],53. 7100 559 45 7253. 7200 581 68 ............. 7363. 7300 605 gl 7463. 7400 628 13 7553. 7500 650 3& 7663, 7600 671 Sa- 7763. 7700 69ol 74 7863, 7800 711 95 7963. 7900 732 17 8063. 8000 754 38 6163, 8100 775 59 8263, ~200 796 · ~1 8363, 8300 818 04 8463. B400 841. 26 8563, 8500 48 8663. 8600 885 72 8763, 8700 909 9a 8~63. 8riO0 931 ]5 6963. 8900 952 36 9063, 9000 973 56 ._ 9153, 9100 993 100 FEET OF SUB SEA DEPTH, . - . VERT I CAL ................... CORRECTION ...... TOTAL COORDINATES 20 ...... .583.40 N 22 605.57 N 24 ......................................... 632.23 N 23 664.1i N 22 697.15 N 21 730.14 N 20 765.G1 N 20 602,48 N 21 ........... 835. :~4 N 22 863,93 N 21- 590.83 N 21 .... 923.87 N 22 903.99 N 23 1005,03 N 22 .105~+.54 N 22 1103.31 N 24 1156.66 N 22 1210.31 N Zl 1265,31 N 21 1320.41 N 20 1375.44 N 2025,02 w 2091.51 2158.51 2222.57 2283.~0 2342.69 2400.17 2455,35 251a.50 2577.92 2641.0~ 2700.~5 2'75'7,91 2813,69 2866.58 2916.18 2965.59 3010.02 3050,67 3090.51 3129.0B _I'~'i-~-RpOLATED VALUES FOR EVEN 10.00 FEET TRUE ~EASURED VERTICAL SUB DEPTH _. DEPTH SEA TOTAL COORDINATES ' ' 1000 999. 936, 2000 .... 199.9, 1936, 3000 2999. gOOO 39&4, 3901, 5000 4793. 69~0,..' 5625, 5562. 7O00 6522. 6459. r:hOO 73U8, 7325, 9000 8213. 8150, 19C)~0_, ~..: 9033. 8970, .0.74 S 1,54 2.5~3 S ' 2,30 3,54 S 1,08 a9,27 N 236 ,.'2a 134.23 5.] 782.51 325.06 N 1301,92 a75,92 N 1711.97 6aO, 24 t,I 2 !75,53 905,78 N 2672,17 1304,08 N 3078.84 3200, VERTICAL SECTION SCALE I"=1000' MOBIL OIL CORP. KUPARUK 2~_- I I - I;::' RADIUS OF CURVATURE METHOD GYROSCOPIC SURVEY ALL DEPTHS SHOWN ARE TVD. m TVD: 9,193 TMD :10,192' HORIZONTAL VIEW SCALE I"- 500' MOBIL OIL CORR KUPARUK 2~.- II - 12 RADIUS OF CURVATURE METHOD GYROSCOPIC SURVEY I TVD= 9~193' . [ ALL DEPTHS SHOWN TMD = 10~192' [ ARE TVD. · 4000 DEPARTMENT OF NATURAL RESOURCES Division of Oil and Gas The File Hoyle H. Hamilton Acting Director June 15, 1976 Diesel leak at Mobil's 22-11-12 well Leak discovered at 2:00 PM 6/13/76. Easy Gilbreth called afternoon of 6/13/76. Sheen on creek and diesel on small lake. Original estimate was 300 to 500 gallons, current estimate (6/14/76) is 100 to 150 gallons. Have boom across outlet of lake and have diesel contained. Also have other booms across lake and now have 90% of diesel cleaned up. Origin.~f leak was from line that connected the 2 fuel tanks to day tank for ~ use. While pumping during the winter, diesel leaked out where the line comes out off,the pad. They don't believe any diesel got into:~the pad. They are currently digging up part of the pad near the leak to confirm this. They have notified all government agencies on ~call list. Ray Morse with EPA is the only one that expressed an interest to possibly visit the location. Obtained the above information ~9'30 AM 6/14/76 from Bill Barlett, Mobil Oil Hoyle H. Hamilton HHH'bjm Mobil Oil Corporation June 3, 1976 State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99503 Gentlemen: KUPARUK 22-11-12 NORTH SLOPE, ALASKA PERMIT NO. 76-9 P.O. BOX 5444 DENVER, COLORADO 80217 TELEPHONE (303) 572-3636 -- C. 'GE'oL 3 GEOL REV DRAFT CONFER: FILE: Attached is monthly report of Kuparuk 22-11-12 drilling for the month of May, 1976. Yours very truly, W, G, Sole, Area Eng±neer Alaska Producing Area /vm Attachment (2) 1R~"V, 3-1-70 STATE OF ALASKA OIL AND GAS CONSERVATION COMMrrI'EE SUBMIT IN DUP. LICATE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 2. N)~E OF OPERATOR Mobil Oil CorDQration 3. ADISRESS OF' OPEI~TOR Box 5444. Denver. Coln. R0?.17 4. LOCATION OF WF_J~L 1,742' from south line & 744' from west line Section 23-TllN-R12E, U.M. Alaska APl ~UMERICAL CODE 50-029-20192 L~SE DESIGNA~ON AND S~IAL NO. ADL 47451- surface loc ADL 28263- Bot. hole loc. IF INIDIA~ AI_,O~T'EE O1~ TRIBE NAME B. ~.'IT FA~ OR ~,EASE .^~(~ (both Mobil-Phillips-Socal leases, WELL NO Kuparuk 22-11-12 ~,FJ~D 4~ND Poo~ oil Fruanoe Bay o~~ Sec.22-TllN-R12E, U.R. ~laska P~IT NO 76-9 13. REPORT TOTAL DlgPq~ AT END OF MONTIrI_. CHA~NGF_~ IN HOLE SIZE. CASING AlX~D CEMF. NTING JOBS INCLUDING DEPTH SET AND VOLLT1VrI~ USED, PF~R~FORATION'S. ~'I"~STS AND RESULTS FISHING JOB~ JUNK IJ',f HOLE AND SIDE-TRACKED HOLE A.ND A2qY o~ER SIGNIFICANT CH3%NG~ IN HOL~ CONT)ITIONS Report for May 1976 Total Depth: 10,192' (MD) 'PBTD 2,406' (MD) Continued drilling 8½" hole directionally to 9773' (MD). Cored from 9773' (MD) to 10093' (MD). Core #1: 9773-9821' Core #2: 9821-9827'; Core #3: 9827-9856'; Core #4: 9856-9916'; Core #5: 9916-9972'; Core #6: 9972-10017'; Core #7: 10017-10044'; and Core #8: 10044-10093'. Ran Eastman Gyro survey through drill pipe to 10,040' (MD). Survey at 10 040' ~ - . , drift 3 , N35ow, displacement N1382.89' & W3~89.03.(D) TVD 9004 76' 4© Drilled 8%" hole to 10,200' (MD). Corrected T.D. 10,192' (MD). Ran electric logs. Took sidewall samples. Ran 7", 29~/ft., S-95, Buttress casing: shoe at 10,172', catcher sub at 10,128', landing collar at 10,115', FO collars at 5749', 4051', 2925' and 2257', liner hangers at 2075', and 2020', and PBR at 2002'. Cemented 7" casing with 500 sx class "G" with 18% salt, 1% CFR-2 and.15% HR-7. Perforated interval 9934-9935' for WSO test. Ran test tool, set packer at 9855' and tested - no formation water was observed. Perforated intervals 9860-9890' and 9910-9935'. Ran test tool, set packer at 9825' and tested. Flowed 1008 B/D of oil with 416 MCF/D of gas through 24/64" surface choke and 5/8" bottom hole choke (Oil gr. 24.7, GOR 412). cont'd. hereby certify ~ th~egoin~;true ~tr~d ~ -~~//~_~~_ ~ . Area Engineer 6/3/76 - ~. ~ ~ ~ . ,,, ~ ~,.~ the Kuparuk 22-11-12 Report for MaY 1976, cont'd Placed cement plug with 27sx Class "G" with 18% salt, 1% CFR-2 and .15% HR-7 from 10,106' to 9810'. Placed BP at 8575' and capped with 18 sx Class "G" cement with top at 8460'. Cemented behind 7" casing through FO collar at 5749' with 227 sx Class G. Cemented behind 7" casing through FO collar at 4051' with 218 sx Permafrost. Placed BP at 3420' and capped with 40 sx Permafrost cement with top at 3312% Cemented behind 7" casing through FO collar at 2925' with 260 sx permafrost. Placed BP at 2429' and capped with 40 sx Permafrost cement with top at 2406'. Displaced the annulus 7" x 13-3/8" with 260 bbls Arctic Pack through FO collar at 2257' to surface. Displaced inside 7" casing from 2203' to surface with 120 bbls Arctic Pack. Nippled down BOPs and nippled up x-mas tree. Rigged down (started midnight 5/28/76) Mobil Oil Corporotion P.O, BOX 5444 DENVER, COLORADO 80217 TELEPHONE (303) 572-3636 May 14, 1976 State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99503 Dear Sir: KUPARUK 22-11-12 NORTH SLOPE, ALASKA PERMIT NO. 76-9 Attached is notice of testing Sadlerochit formation in the subject well. Yours very truly, ~. G. SoZe, ~ea ~g~eer ~laska ~ro~uo±~g ~ea PKP/vm att. (3) Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate Form 10-403 REV. 1-10~73 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) ~' O,L !--~ GAS [--] WELL 1.2-J WELL OTHER z NAMAg~%PfR~Ti~ Corporation 3. ADDRESS OF OPERATOR Box 5444, Denver, Colorado 80217 4. LOCATION OF WELL At surface 1,742' from south line & 744' from we st Section 23-TllN~,R12E, U.M., Alaska line 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 63' (RT) 14. CheCk Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20192 6. LEASE DESIGNATION AND SERIAL NO. ADL 47451- surface loc ADL 28263 - Bottom Hole 1OC 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME (both Mobil-?hillips-Socal leases) 9. WELL NO. Kuparuk 22-11-12 10. FIELD AND POOL, OR WILDCAT Oil Prudhoe Bay Fld,Prudhoe BayPoo' 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 22-TllN-R12E,U.M.,Alaska 12. PERMIT NO. 76-9 3ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPA, R,.~'~,~% Sadl~r~ (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* _ (;HANGE PLANS :hit SUBSEQUENT REPORT OF: WATER SHUT-OFF [~ REPAIRING WELL FRACTURE TREATMENT ~.~ ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent cletalls, and give pertinent dates, including estimated date of starting any proposed work. The attached is testing procedure for the subject well. This procedure was conveyed verbally to Mr. Loney Smith by Mr. P. K. Paul on 5/14/76 at 1:00 pm (Denver time) and verbal approval was given right at that time. 16. I hereby certify that the??/egoing i~Arue and correct TITLE Area Engineer May 14, 1976 DATE (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE. DATE See Instructions On Reverse Side TESTING PROCEDURE KUPARUK 22-11-12 1. Complete up through step 2 of 7" Casing and partial completion program and then test as follows: 2. Perforate interval 9948-9949' with 4 shots per foot (depths are as per DIL log) for WSO test. 3. Run in hole with packer test assembly. Set packer 50'+ above the top of perforations and perform a drill stem test (only one flow period of 2 hours, without any shut in period). 4. If formation water is observed in above test then squeeze the perforations with cement. Otherwise continue with the procedure without squeezing. 5. Perforate Sadlerochit intervals 9860-9890'and 9910-9935' with 4 shots per foot (depths are as per DIL log). 6. Run in hole with packer test assembly. Set packer 50'+ above the top of perforations and perform a drill stem test as described below. a) Two inside pressure recording bombs should be in the test assembly below the bottom hole choke, and two outside pressure recording bombs should be placed below the perforated pipes. b) A single stabilized rate with less than 1% BS&W in the 1500 B/D range should be taken. A six to eight hour clean up and stabilization period would not be unreasonable in this area. c) Duplicate separator oil and gas samples should be taken during the stabilized flow period. d) The final buildup period should approximate 1-1/2 times the duration of the flow period. e) After the buildup test is completed, the well should be conditioned before trapping a bottom hole reservoir fluid sample. The well should be flowed at a low rate, in the 200 b/d range, for up to 12 hours. If accurate gas and oil readings can be obtained at this low rate, the GOR should be recorded. If the GOR and surface pressures remain stable, the bottom hole sample can be taken after eight hours. f) After retrieving the bottom hole sampler, a check for single phase oil should be made before transferring samples to the shipping containers. If gas is produced, the pressure in the sampler should be increased and the sampler should be agitated to force the gas back into solution before making the transfer. g) All surface data normally taken during a production test should be recorded. The Sadlerochit test at Gwydyr Bay NO. 1 was noted as an excellent example and is a guide for this testing. 7. Spot cement plug across the perforations up to lO0' above Tag top of the plug. *Kuparuk 22-11-1 2 Testing Procedure - contd. 8. Continue with step 3 of 7" Casing and Partial Completion Program. PKPaul -DFWivchar 5/14/76 TESTING PROCEDURE KUPARUK 22-11-12 1. Complete up through step 2 of 7" Casing and partial completion program and then test as follows' 2. Perforate interval 9948-9949' with 4 shots per foot (depths are as per DIL log) for WSO test. 3. Run in hole with packer test assembly. Set packer 50'+ above the top of perforations and perform a drill stem test (only one flow period of 2 hours, without any shut in period). 4. If formation water is observed in above test then squeeze the perforations wi th cement. Otherwise continue wi th the procedure without squeezing. 5. Perforate Sadlerochit intervals 9860-9890'and 9910-9935' with 4 shots per foot (depths are as per DIL log). 6. Run in hole with packer test assembly. Set packer 50'+ above the top of perforations and perform a drill stem test as described below. a) Two inside pressure recording bombs should be in the test assembly below the bottom hole choke, and two outside pressure recording bombs should be placed below the perforated pipes. b) A single stabilized rate with less than 1% BS&W in the 1500 B/D range should be taken. A six to eight hour clean up and stabilization period would not be unreasonable in this area. c) Duplicate separator oil and gas samples should be taken during the stabilized flow period. d) The final buildup period should approximate 1-1/2 times the duration of the flow period. e) After the buildup test is completed, the well should be conditioned before trapping a bottom hole reservoir fluid sample. The well should be flowed at a low rate, in the 200 b/d range, for up to 12 hours. If accurate gas and oil readings can be obtained at this low rate, the GOR should be recorded. If the GOR and surface pressures remain stable, the bottom hole sample can be taken after eight hours. f) After retrieving the bottom hole sampler, a check for single phase oil should be made before transferring samples to the shipping containers. If gas is produced, the pressure in the sampler should be increased and the sampler should be agitated to force the gas back into solution before making the transfer. g) All surface data normally taken during a production test should be recorded. The Sadlerochit test at Gwydyr Bay NO. 1 was noted as an excellent example and is a guide for this testing. 7. Spot cement plug across the perforations up to 100' above Tag top of the plug. ~ Kuparuk 22-11-12 Testing Procedure - cont d, 8. Continue with step 3 of 7" Casing and Partial Completion Program. PKPaul ' DFWivchar 5/14/76 Mobil Oil Corporation P.O. BOX 5444 DENVER, COLORADO 80217 TELEPHONE (303) 572-3636 May 13, 1976 State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99503 Dear Sir' KUPARUK 22-11-12 NORTH SLOPE, ALASKA PERMIT NO. 76-9 Attached is corrected page No. 2 of 7" Casing and Partial Completion Program mailed on May 12, 1976, with the P-3 Form. Yours ve~w truly, //I ~//- /C W. G. Sole, Area Engineer Alaska Producing Area PKPaul/vm att. Mobil Oil Corporation P.O. BOX 5444 DENVER, COLORADO 80217 TELEPHONE (303) 572-3636 May 12, 1976 State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99503 Dear Sir: KUPARUK 22-11-12 NORTH SLOPE, ALASKA PERMIT NO. 76-9 !' 4 FNG '-'!-' I s ~r,,'c- I !3 a~OLI - .._]... ~,~v CON~R: ' FILE: Attached is notice of 7" casing run and cementation for the subject well. Yours very truly, W. G. Sole, Area Engineer Alaska Producing Area PKP/vm Att. (3) · REV. 1-10-73 · Submit "1 ntentlons" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 5. APl NUMERICAL CODE 50-029-20192 6. LEASE DESIGNATION AND SERIAL NO. ADL 4745] - surface 10c. ADL 28263 - Bottom Hole loc. 7. ,F ,ND,AN. ALLOTTEE OR TR,BE NAME ~' O,L l--P! GAS ~ WELLL~,J WELL OTHER NAME OF OPERATOR Mobil 0il Corporation 8. UNIT, FARM OR LEASE NAME Mobil-Phillips-Socal (both leases) 3. ADDRESS OF OPERATOR 9. WELL NO. P. 0. Box 5444, Denver, Colorado 80217 Kuparuk 22-11-12 4. LOCATION OF WELL At surface 1,742' from south line & 744' from west line Section 23-TllN-R12E, U.M., Alaska 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 63' (RT) 14. Check Appropriate Box To Indicate Nature of Notice, Re 10. FIELD AND POOL, OR WILDCAT Pool Prudhoe Bay F]d, Prudhoe Bay 0il 11. SEC., T., R., M,, (BOTTOM HOLE OBJECTIVE) Sec.22-TllN-R12E, U.M. Alaska 12. PERMIT NO. 76-9 )orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) 7" casing PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS cementing SUBSEQUENT REPORT Of: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. The attached is "7" Casing and Cementing" procedure for the subject well. Other pertinent details are: Total Depth 10,192' (MD) Sadlerochit Top 9,792' (MD) Shublik Top 9,772' (MD) Sag Top 9,744' (MD) This procedure was conveyed verbally to Mr. H. H. Hamilton by Mr. P. K. Paul on 5/6/76 at 1:00 p.m. (Denver time). On 5/7/76 at 11:45 a.m. (Denver time) Mr. Loney Smith gave verbal approval to go ahead with the procedure. 16. I hereby certify that the f~regolnggis true and correct 51GNED . v' ' · ; - - Area Engineer T IT LE DATE May 12, 1976 (This space for State office use) APPROVED BY_ '/'k_ TITLE - ~C. ,/ ' '~- ' CONDITIONS O~PPROVAL, IF ANY: DATE See Instructions On Reverse Side Reamed ~ 7" CASING & PARTIAL COMPLETION PROGRAM KUPARUK 22-11-12 Complete up through step 2 and then perform Sadlerochit test, if required, as per testing procedure. Then continue with step 3 of this procedure. PROCEDURE 1. Run 7" O.D., 29#/ft., S-95, Buttress casing with shoe at T.D. Other tools to be run and running procedure should be as follows' a) Other toOls - 7" centralizers - 16 or as required 7" float shoe - 1 7" float collar- 1 7" F.O. Collar- 4 7" x 13-3/8" hanger assembly & tie back sub - 1 7" pup joints - 6 b) During drilling, condition and build mud weight, if necessary, to ensure a minimum of 10.2 ppg then circulate mud with the same annular velocity used during drilling until the shale shaker clears up (Maintain mud gel strength of at least 20#/100 sq. ft. less than the cement.) c) Maintain casing running speed - 1 ft/sec. d) Place float shoe on bottom of first joint (use Bakerlok or equivalent on threads). e) Run float collar one joint above shoe (use Bakerlock or equivalent on threads). f) Put 7" centralizers on each joint up to top of expected pay zone (9744' MD) g) Run two F.O. collars, one at 5700'_+ and another at 4000'+, with one centralizer directly above and one directly below of each collar. h) Run two F.O. collars, one at 2900'+ and another at 2200'+, with one centralizer direclty above and one directly below of each collar. i) Run 7" x 13-3/8" hanger assembly and tie back sub so that the 7" casing can be hung and tripped from 2000'+. 2. Cement 7" casing with class "G" w/18% salt as follows' a) Condition mud and circulate hole clean with same annular velocity used during drilling. Maintain minimum mud weight of 10.2 ppg. b) Pump 20 bbl. of B. J. mud-sweep or equivalent and 20 bbl. of water ahead of cement slurry. 2~ c) Drop bottom cementing plug. d) Mix and pump class "G" cement with 18% salt. Amount of cement should be determined to cover from shoe to 1000' above the top of the pay zone. e) Pump down top cementing plug and displace with minimum mud weight of 10.2 ppg. 3. Run and set 7" cast iron bridge plug at 200'+ above top of Permo-Triassic pay and place 100' cap with class "G" cement. Tag top of the plug. 4. a) Cement 5700'to 5200' through F.O. collar at 5700' with class "G" cement with 18% salt. b) Cement 4000' to 3500' through F. O. collar at 4000' with Permafrost cement. c) Run and set 7" cast iron bridge plug at 3400'+ and place 100' cap wi th Permafrost cement. Tag top of the plug. 5. Run drill pipe with packer and F.O. collar opener. Open F.O. collar at 2900'+. 6. Cement 7" casing from 2900'+ to 2500'+ with Permafrost cement. Immediately close F.O. collar. 7. Run and set 7" cast iron bridge plug at 2400'+, and place 100' cap with Permafrost cement. Tag top of the plug, 8. Run drill pipe with packer and F. O. collar opener. Open F.O. collar at 2200'+_ then set packer. 9. Flush and clean 7" x 13-3/8" annulus with water until mud is displaced and cleans up. 10. Place "Baroid Arctic Casing Pack" of at least 10.2 ppg weight in the annulus of 7" x 13-3/8". Release packer and immediately close F.O. collar. 11. Displace inside 7" casing from 2200'+ and above with "Baroid Arctic Casing Pack" of at least 10.2 ppg. weight. 12. Place X-mas tree and seal all annuli with valves and bull plugs, Note- The mud to be left inside 7" casing should have at least 10.2 ppg weight so that total hydrostatic head of fluid column inside 7" casing over balances Permo-Triassic reservoir pressure (approximately 4300 psi.) PKPaul 5/12/76 Mobil Oil Corporation May 4, 1976 State of Alaska Department of National Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99503 Gentlemen: KUPARUK 22-11-12 NORTH SLOPE, ALASKA PERMIT No. 76-9 P.O. BOX 5444 DENVER, COLORADO 80217 TELEPHONE (303) 572-3636 t ' Attached is monthly report of Kuparuk 22-11-12 drilling for the month of April, 1976. Yours ver~ truly, PKP/vm Attachment (2) Form No. REV. 5-1-70 STATE OF /~LASKA SUBMrr IN D~m.,.ICAT~ OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT O'F DRILLING AND WORKOVER OPERATIONS WILL W~:LL OTHER NAME OF OP]~:~.ATOR Mobil Oil Corporation ADDRESS OF BOX 5444, Denver, Colorado 80217 ,, 4.~CA~ON OF WELL 1,742' from south line & 744' from west Section 23-TllN-R12E, U.M. Alaska line Apl NL~.~ER1CAJ~ CODE 50-029-20192 ~ [.~SE DESIGNATION AND S~IAL NO. ADL 47451-surface lse. ADL 28263-Bat.Hole loc. 8. ~.'~T F.~Z'~ oR :E^S: .~a~ (bu i.h Mobil-Phill ips-Socal leases) VV~!.L .'%'0 Kuparuk 22-11-12 F~ ^_~D POOL. OR wr~.~cATPrudDo~ Prudhoe Bay Fld.,Oil Pool sec. T.. R.. M. (BOSOM HO~ o~~ A1 a s k a Sec. 22-TllN-R12E, U.M. 12 PE1TMIT I~0 76-9 13. REPORT TOTAL DEPTH AT END OF MON~'i'H. CI-IJkI'~GES IN HOLE SIZE, CASING AND CEMF. JqT!NG JOBS INCLL'DING DEPTH SET AND VOLLTMES USED. pERFORATIONS, 'I-ESTS A.N'D HESULTS FISHING JOBS JY~"ATK IN HOLE AND SIDE-T]~,ACKED HOLE AND ANY OTHER SIGNIFICAblT CIiA. N~ES IN HOLE CONDITIONS Report for April 1976 Total De.pth: 9,697' (MD) Continued drilling 8½" hole directionally to 5755' (MD). While drilling at 5755' (MD) with Dynadrill, the drilling string stuck. Various attempts to release the stuck pipe failed. Backed off at 4980' (MD) - fish left in the hole consisted of bit, crossover sub, Dynadrill, bent sub, crossover sub, 4 Monel drill collars, 5 steel drill collars, crossover sub and 16 joints of heavy wall drill pipe. Further trials to recover fish were unsuccessful. Spotted cement plug above the fish with 125 sx class "G" cement with 1½% CFR-2 and 2% CaC12. Tagged cement stringers at 4433'. Drilled cement stringers and dressed off cement plug to 4831'. Side tracked the old hole form 4831'. Continued drilling 8½" hole directionally to 9697' (HD). Survey at 9697' (MD) - TVD 8771', drift 36½°, N41°W, displacement Nl189' and W3003'. lherebyeertifyth~tthej°~4~°iag~eanti~°rre~ Area Engineer May 4, 1976 NOT[--Report on this form is requir~ each calendar ~nth% regardless of the ,to,us of operations, and must ~ filed In duplicate ~ith the 0il and gas con,ervotion comm iffee by the 15~ of the ~ucc~ding mon~. u~l,~ 0therwi,~ directed. Mobil Oil Corporation P.O. BOX 5444 DENVER, COLORADO 80217 TELEPHONE (303) 572-3636 April 2, 1976 · State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Anchorage, Alask 99503 Gentlemen- KUPARUK 22-11-12 NORTH SLOPE, ALASKA PERMIT NO. 76-9 Attached is monthly report of Kuparuk 22-11-12 drilling for the month Yours very trulyo~ W. G. Sole, Area Engineer Alaska Producing Area of March, 1976. ....... ~ ;]' (. ' D:~AFT CONFER: -i ~: PKP/vm attachment (2) Fc~rm ~o~ P.-.4 ~. 3-1-70 STATE OF ALASKA OIL AND GAS CONSERVATION CO/VCv~I~EE SUBMIT IN DL?L1CATE MONTHLY RE!PORT OF DRILLING AND WORKOVER OPERATIONS 2. NAME OF OPEP~TOR Mobil Oil Corporation 3. ADDRESS OF O~ERA, TOR Box 5444, Denver, Colorado 80217 1,742' f~om sou~h ~ine & 744' Section 23-TllN-~2E, U.~., I 5 API NI32%~[ERICAL CODE J6 LEA~E DESiG/'~ATION A.'D SERIAL NO. JADL 47451 - Surface loc. !ADL 28263 - Bot. Hole loc. IF INDIA],~ ALtT~ fEE Ol~ TRIBE NAME ~. ~,~IU' ~^m~ OR LE^S~ .AMS (both Hobi 1-Phi 115ps-Socal leases) 9 WELL NO Kuparuk 22-11-12 10 FLF. LD /~ND POOL. OR XVILDC.AT Prudhoe Bay Fid, Prudhoe 05] Pool ti SEC. T.. R.. I%¢, (BOT'TOM HOLE oB,rSC~ Sec. 22-TllN-R12E, U.M. Alaska lg PERi--IT NO 76-9 . 13. REPORT TOTAL DEPTH AT END OF MON~'I/-I, CHANGES IN HOLE SIZE, CASING AND C~-'VIENT]]~G JOBS INCLUDING DEPTH SET AN]) VOLU1VIE-X~ USED, PEH_FOtL~TIONS, ?~STS ~ RESULTS FISHING JOB~ JI~K LN HOLE AND SIDE-TY{~CKED HOLE A2qD ~Y O~R SIGNIFIC~T ~G~ ~ HOJ~ ~N~ITIONS REPORT FOR MARCH 1976 TOTAL DEPTH' 4,150' (MD) Drilled 36" hole with rat hole machine to 53' from matting board (71' from K.B.) Set 30", 156#/ft., LP conductor at 53' from matting board (71' from K.B.). Cemented to surface with 125 sx Permafrost cement. Spudded on March 8, 1976 at 9:30 a,m. Drilled 17-1/2" hole to 750'. Reamed 17-1/2" hole to 26" up to 750'. Ran 735' of 20", 94#/ft.,H-40, Buttress casing.and cement to surface with 4000 sx Permafrost cement. Ran 20" guide shoe at 735', duplex collar @ 689' & subsea hanger @ 240'. Nippled up 20" OCT head and tested to 400 psi~ Nippled up 20" BOP stack and tested to 500 psi. Drilled collar, cement and shoe. Drilled 12-1/4" hole to 2750'. Ran electric logs. Reamed 12-1/4" hole to 17-1/2" to 2350'. Drill pipe backed off at 570' while reaming hole. Recovered all of fish. Reamed 12-1/4" hole to 17-1/2" to 2750'. Ran 2723' of 13-3/8",72#/ft,N-80, Buttress casing with float shoe at 2723', duplex collar @ 2690', FO collar @751' and OCT subsea hanger @ 240'. Cemented with total 5000 sx Permafrost cement. Lost returns when 4800 sx in; observed slight traces of cement with return. Ran 2-3/8" tubing in 13-3/8" x 20" annulus and cemented to surface w/150 sx Permafrost cement. Installed 13-3/8" s'lip-on head and tested to 3000 psi. Nippled up 13-3/8" BOP assembly & tested to 5000 psi. Drilled duplex collar, cement & shoe. Drilled 12-1/4" hole to 3000'. Kicked off at 3000' for direction hole and directionally drilled 8-1/2" hole to 4150'(M.D.). Continued drilling. -14. I hereby certif~ ~ the and correct ,/~f//.A/_~/~.2/1///~ ~ Area Engineer ~ Apri 1 2, 1976 NOTI~ --Report on this form is required for each calendar month~ regardless of the status of operations, and must Im filed In duplicate with the oil and gas conservation committee bythe 15th of the succeeding month, u~tle~ otherwise dir4cted. of ALASKA DEPART~'~'~T OF ~-.!^T,~FU~L RE,.,OU ~.CES ~ivision of Oil and Gas TO: ~U,~ K. Gilbreth,. Jr. Di rector Chief Petroleum EngineeW~'' F~O~: RuSSell A. Douglass Petmoleum Engineering Consultant DATE .' April 1, ~:,~ SUBJECT: !~itness ROPE test, Hobil Kuparuk State 22-11-12 S~27,_ 1976.- TraVeled from BP operations center to Parker P~i~ %. Tt~ted On J'the Mobil Kuparuk State 22-11-12 drillsite. Purpose of the trip was to ~yitness ROPE testing. Started testing at 9:00 PM. Lower and upper kelly valves failed to hold 5000 psig. Still working on stack. Sunday. Narch 28, 1976 - Started testing stack, choke and kill lines and manifold ~-~5~§;~-A~,-~hey are using diesel for testing. All thirteen valves in manifold tested to 5000 psig. Pipe rams ~and choke line'' · ... w~ng valves to 500~ psiq Check valve and kill line wing valves to 5000 psig. Annular preventer to 2500 psi~ and blind rams to 5000 psig. . They plan to change out upper and lower )¢elly valves before drilling ahead. The rig had no nitrogen backup system. I filled out a field inspection report. I stipulated repair or replacement of upper and lower kelly valves and installation of a nitrogen backup system for the blow-out preventer accumulator. ! gave the report to Ken Sullivan and a copy is attached. On March 31, 1976 Ken Sullivan called our Division office to inform.. ~]s the kelly valves had been changed out and. tested to 5000 psig and that the nitrogen backup system had been installed. In summary I ~-~itnessed ROPE testing on Mobil's Kuparuk State 22-11-12 drillsite. Two valves failed to hold the required pressure and there was no nitrogen backu? ~ 1 system for the preventer stack. These problems were corrected by .~'.,arch 31, 97~. Attachment Feb~ary ~, 1976 Re: ~bil-Philli~-Socal Kuparuk 22-ll-12 Mobil 0t1 ~rporatim~ State Permit ~. 76-9 W. G. ~le Area Engineer ~bit Oil Corporation P. O. E)ox 5444 TA Denver, Coiora~ 80217 ~ar Sir: Enclosed is the a~roved application for permit to drill the above referenced well at a location in Section 22, Township llF~, ~an~e 12E, Ut4. ~ell samples, core chips and a mud log-are not required. A directional survey i s required. ~ny rive~ in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in ~ese a~as are subject ~ AS 16.50.~70 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code}. Prior to con~nencing o~rations you ~y be contacted by the Habitat Coordinator's office, Depart- ~nt of Fish and Ga~e. Pollution of any ~aters of the State is prohibited by AS 46, Chapter 03, Article 7 and the regulations prolmulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70} and by the Federal Water Pollution Control Act, as a~nded. Prior to c~cing operations you may be contacted hy a ~epresentative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Departn~nt of Labor is. being notified of the issuance of this permit to drill. To aid ~ in scheduling field ~ork, we would appreciate your notifyin~ this office ~ithin 48 hours after the ~ell is spudded, l~e ~ould also like to be notified so that a representative of the Division may be present to witness testin~ of blowout preventer equi~ment before surface casing shoe is drilled. t~. G. Sole 2- February 2, 1976 Operator ~Jst su~it plan for and receive approval of a producing casino string design if well is to be completed as a producer. In the event of suspensi~ or abandonment please give this office adequate advance notification so that we may have a witness present. Very truly yours, O. K. Gilbreth, Jr. Chairman Alaska Oil and Gas Conservation Conmittee ~:~j~ Enclosure cc' Department of Fish and Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Departmmnt of Labor, Supervisor, Labor La~.~ Compliance Division w/o encl. Drlg. Permit No.~~ Operator ~ ~ll~~ ' a ~ and Gas [enservation Com~ ee Field Inspection Re,port /~/J~&/~ I/~-~ Well/Platfm Se c,~T._~_.~___ q ~,l , _.L~ .__~i Represented by~,__~~___~lame & Huml)er~.~~ ..... ~~_] .... Satisfactory Type~nspection Yes No Item (~l~ocation,General (~() (~' ( ) (~ () () () () () () () () () () () (), () () () () () 1. Well Sign 2. General Housekee]~g 3 Reserve Pit-(l~F~,pen( lfilled 4. Rig ( ) Safety. Valve Tests 5. Surface-No. Wells 6. Subsurface-Ho. Wells ( ) Well Test Data 7.':Well Nos. , , , 8. Hrs. obser , , 9. BS&W , , , lO. Gr. Bbls. , , , ( ) Final Abandonment ll. P&A Marker 12. Water well-( )capped( )plugged Sa ti s Factory Yes No Item (mW'() -'~'5'l~'-~:~:~S'~nq'~et (~() 16 '~e~-t fluid-( ),,,~l:F-;~)mud (~oi~ (~() ~ 17 Master ttvd. Control $ys.- psig ( ) (~ ~; ~ ( ) 19 R&~()te Controls (~() 20 Drillinq spool- ~ 'ouL~ets (~() 2~ Ki~ Lii~e-(~h~'~-va~ve (~/() 22 Choke F]owline ( ) HCR valve (~ ( ) 23 Choke ~ani~]d No. valvs~flgs_ (~() 24 Chokes-(~emote( )Pos~(~,i. ~ ( ) ~5 Test Pluq-( )Wellhd(~so( )none ~ ( ) ~6 Annular ~reventer~psifl (~ ( ) 28 Pipe Rams~_m.~_.psig --) (~ 29 Kelly & Kelly-cock ........ psig ( ) ( ) 13. Clean-up ) ~(,~ 30 Lower Kelly valve psig ( ) ( ) 14. Pad leveled ~( ) 31 Safety Floor va-lve~¥-(---]'BV ( )Dart Total inspection observation time ~~~ays Total number leaks and/or equip. 'Failures~ Rem. arks~,~~j. ~.. ~_' -~~ ,j ~ ~-~ ~_~ '., ~ ~, ~-- ~ .............................. &:F-~ .... ~lO~fy' in ~ d~or wh~ rea~ ' In~cted by~~Date~~ Alaska ~ and Gas Conservation Committee Field Inspection Report -Drlg. Permit No. Well/Platfm Sec T q__, ~! Operator Represented by Name & Number Satisfactory Type Inspection Yes No Item ( ) Location,General () () ~.,() () ~ () () ()() () () 1. Well Sign 2. General Housekeeping 3. Reserve Pit-( )open( )filled 4. Rig ( ) Safety Valve Tests 5. Surface-No. Wells 6. Subsurface-No. Wells ( ) Well Test Data 7. Well Nos. 8. Hrs. obser , , , 9. BS&W , , , 10. Gr. Bbls. ( ) Final' Abandonment ll. P&A Marker () () () () () () () () () () () () () () () () Total inspection observation tii~e Remarks SatisFactory Type Inspection Yes No Item () BOPE Tests () () () () () () () () () () () () () () () () () () () () () () () () () () () () 12. Water well-( )capped( )plugged ( ) ( ) 13. Clean-up ( ) ( ) 14. Pad leveled ( ) ( ) 15. "Casing set (a 16. Test fluid-( )wt~--(-)mud ( ) oil 17. Master Hyd. Control Sys.- psig 18. N2 btls. , , , psig 19 Remote Controls 20. Drilling spool- "outlets 21. Kill Line-( ) Check valve 22. Choke Flowline ( ) HCR valve 23. Choke Manifold No. valvs fl~s 24. Chokes-( )Remote( )Pos.(--)~.dj 25. Test Plug-( )Wellhd( )cs~( )none 26. Annular Preventer,~_psiu 27. Blind Rams, ~psig 28. Pipe Rams psi§ 29. Kelly & Kelly-cock psig 30. Lower Kelly valve psig 31. Safety Floor valves-( )BV ( )Dart hrs/days Total number leaks and/or equip, failures cc' Notify in days or when ready Inspected by Date Term' I0-- 401 STATE OF ALASKA SUBMIT IN TRIP] (O~her mnstm2etlons reverse side} OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN DEEPEN DRILL [] ~).-; TYi*s¢ 07 'W~LL W~LL '.~ WE'L~ OTH~ ZON~ ZON~ ~ N~3,?L OF Og~TO~ 2[pp:ii. 'Of! Corporation 3 ATJDR~ ~ OPhiR P,O.. Box 5444 Th~ Denver, Colorado 80217 4.LOCATION OF WELL1 A:,,rfac~ ,742' from south line & 744' from west lira of Sec. 23-TllN-Ri2E, U.M., Alaska z~oo A=p,-o~,,~pr0~.,-o~.~~<~from north line & ~-~4~' line of Sec. 22-~%~iN-R12E, U.M., Alaska API # 50-029-20192 ADL 47451-Surface Loc. ..ADL .28_263-BOt- Hole Loc FARM OR LE~SE ~E(both lea- Mob( 1-Phi!.liPS,Soqa~l/ses i i~<ELL NO. .Kuparuk 22-11-12 13. DISTANCE tN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE~ ApproximatelY 17 miles Nq~ of Deadhorse ,~. ,GNp IN~O~,,^T~ON' Pacific I~de~ani'ty co. TYPE' OIL&GaSs~e,>.~.d:~r~o. 243305 (expires 8/18/76) 15. DISTANCE FROM PROPOSED' ~ ~"(~)O - I'18' LOCATIO~ ~o PROPERTY OR LEASE LIN~, FT. ~! 2 , 5 6 0 1 Ba'y Fle±~, '.Prudhoe Oi1 .Pool [ ti. SEC., T,. R.. M.. ~BOTTONI I -- HOLE OF=JECTIVE~ ' _ from east ]~ec- 22-TI1N-R12E, [U.M..,.. Alaska ~...~, $100,000.00 17. NO. ACRE,S ASSIG.N/ED TO ~m~s W~LL 32 0 NO. OF ACRES IN LEASE (Also to nearest dr(g, unit, if any) TO NEAREST 'WELL DRILLING, COMPLETED. 6,500 ' i ..,,,...,,,, ~ ,, . D. ) ' OmAPPL'EDFOR'~T'from Kup.2i-ll-12 [ 10,200' (M.D.) Rotary 21. ELEVATIONS (Show whether DF, RT, CR, etc.} 99. AppR~k.,DATE WORK WIt. L START' 65' DF February 1~ 1976 . _ SIZE OF HOLE SiZE OF CASING WEIGHT PER FOOT I~. GRAI)E !' SETTING DEPTH quantity of cement 36" :" :~ 30" ~' 154 --: '~'J-55 ' 80'""q: ' 3OU SX ....... 2----~-.,, . ~1'20'i~ .... 94 H'40 750,* - 2,160s1~ .... ],7~" .... 13".'3/8".'. ' .... 72 . .N'-8'0 "2.?00i~= .... ~,r, 52,'Ssx ,' ........... R½" . 7Y ..... 29 g-95 10.200':~ "c0mP!.etion .p, rocjram' WIT, 1. .... ]..... · .... for~ar~ed ......... The well is to be direct(anally drilled from the surface location described above. The bottom hole target will be approximately 3,500' northwest of the surface location as described above. The primary objective is the Permo-Triassic pay zones. The vertical depth, of the well would be 9,200". Following are attached with the application: 1) Blowout prevention program: Figure 1-BoO.P. assembly on 20" csg. from 750' to 2,700'; Figure 2-B.O.P. assembly on 13 3/8" csg. from 2,700' to T.D.; Figure 3-Choke manifold. 2) Survey Plat. II%' ABOV~ 5t:'AC~ D~I~RIIBI~I F'ROI~OSE'T) ~R.~: Ii ~I Is to dee~n ~tve ~ on vresent ~u~lve zO~ ~ pm~ r~w p~du~lve zone, .If p_~t is w Orlll or ~n a~io~lly, .~lVe ~menT ~u%' on s~bsuMa~ ~ ~d mea~ ~d ~ue 've~ical dept. Give-bl~u{ preventer' p~gram,, ~. ~ h.~y ~t~, ,~t~o,~,o~l~ . , Area Engineer s,c~-~ ~A~ December 31 1975 , ', ,, ,. " , , IThis space for State office use) CONDITIONS OF APPROVAL, IF ANW: r~ l R.EC'YI. ,ONAL SURVEY ~ v?'~. [] NO 1VIUD LO(] · OTKE~ F~E~UIR~NTS: A.P.I. ~CAL COD~ 50-029-20192 February 2, ,,1976 , m.~=February 2; 1.976 Jaxeaaz~ 27~ _L97fi lease operations outlined in your let~_r of ~ 15, 1975, as ~ ~ 1~~ of ~ ~, ~75 m~ J~f 2~ 1976, ~- h~y ap~v~ .. B!~.~irg or r~ of ~n~ir~ or vegetative cov~r is prohibited. Ic~ roads~ be c~nstructed for all transporta~bon o~rations ~ ~ar~--a areas incluiirg ~xis~Lng winter trails. 5~ese roads shall i~ construc~ ~d r~i~n~ in a n~anner 'that will prevent dam~e to the txn-zira. Ice roads are ~t re~r_e~ x.~b~ere there is 3~ t 5~ 7~ Sea ice travel shoul~ be used as n~ch as POssible .for. travel to '" l~inintize ~ ~_~_rface tz~vei. One route suggested is to ~-avel frcm Beecb~=y Point on tD~ sea ice and up tb~ S~or~y~zak Pgver as far as possible. .. After April 15, 1976, t~ use of grour~t contact vehicles s5~li subject to e_e ~rm!__r~t_~_on within 72 hours of notifi~on by 'the Director.... ,.,. .. ,- ~.::~, . ~ equi~ shall enter or cross acW_ive (open flowing) charmels of i' .:' · . v~ter~ses ar~ the tmr~k (a) of the ~tercour~ sb~ll not be_ altered.. ~ . · . .'. ~,~ter~ removal si~!! only be frcm exposed(d~ntered) bars of watercourse to tbs ~xisting ice or ~ter level. ~ shall in such a ~r that tbs wa ~ter fl~ of the ~tercourse sha]! r~t ~, blocked or di~..., . 8. Th~ st~es n~st be clea~Iy marked as to hhe name of ~y' ~.~bil Oil Corporation Page 2 January 27, 1976 9~ 10. Prior to spring breakup or upon completion of material removal the mining site(s) shall be gr ~/ed m~oth with all banns and potholes r~, and al! depressions filled to prevent en- ~t of fish. Ail material incl~n~ stockpiled material ~ust be re~oved fr~n the floodplain prior to spring breakup or ~tay 15, 1976, whichever occurs first. The Department of Fish ~ Gam~_, Habitat Prohection Sechion, 1300 College Road, Fairbanks, Alaska 99701(p~ne 452-1531), sb_a]! be notified at least 14 days prior'to ~x~m~_nt of ~t~~ favor-al operaticns a~ ~ upon ca~p].~or, of o~aticn~. An accounting of' tb~ mmber~ used for each constru~u_ion featmtre (road,~, ehc.) based on inplace n~_asur~..nen~ ah ~'~in't= of use must be filed witch ~he c~n~letion report. Th~ reserv~ ~ pit rmast be constructed with adequate capaciLy to c~nta/n the ~ohal anticipated n~d and fluids at the drill Site plus an adequate saf~ay margin for ~~ep~y situations. R~e mud pit and fuel storage areas nmst be construct~ ar~ situtated so that ur~___er ~rmal and ~~ situations ~?aterials will not leak or overfl~w into the surround~ areas. For Constructinn standards to c~nply with this stipulation contac~ the Director of the Division of Oil ar~ Gas. 14. ~ter ~r~atmant faci!i~ s'na!l l~ve fj]Lkers capable of removing parhi~ of 10 microns or less. If the Sept~ber 1975 man~ for tb~ Parker drY_Il rig has been updated please ~send a o~py of the update to Department of Envirorm~ntal Conservation, %Jerry I~ossia, P.O. Box 1601, Fairbanks, AlaSka 99707. 15. ~ Director ~y re~re ~at his authorized represen~a~i.'ve be on site during any operations under this appr~ral. 16. Any disturbed areas shall be repaired to -khe satisfaction of the D~ect~r. 17. A copy of the application and approvag letter shall be placed in a prcmir~nt location in the operators camp. 18. 19. A cc~pletion report sh~]l be filed within 15 days of completion of operations. Very truly yours, .PEDRO DENTON bce: NC District, ADF&G, D~ AtlanticRichfieldCompany North Americ~'~ .~cing Division Alaska Explom..~n & Producing Operations Post Office Box 360 Anchorage, Alaska 99501 Telephone 907 227 5637 O. G. Simpson North Alaska District Manager January 26, 1976 State of Alaska Departm_nt of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99503 Attention: Mr. H. W. Kugler Subject: Letter of Non-Objection Mobil Kuparuk 22-11-12 North Slope, Alaska Gentleman: Atlantic Richfield Company has been furnished with a copy of Mobil Oil Corporation's request for Permit to Drill Kuparuk 22-11-12. This well will have a surface location 1742' from the South line and 744' from the West line of Section 23, NllN, R12E and a sub-surface location in the prospective productive zone 2500' from the North line and 2500' from the EaSt line of Section 22, TllN, R12E. Atlantic' Richfield Company as operator of Atlantic-Exxon State Lease ADL-28264 covering Sections 25, 26, 35 and 36 TllN, R12E, has no objection to the issuance of the permit as requested. Very truly yo.urs, ATLANTIC RIC/-IF'n~,D COMPANY ~. G. S i~son North Alaska District Manager cc: 5~bil Oil Corporation Attn: Mr. Ralph Ponfick Exxon Corporation Attn: Mr. Roy Lynam OGS/JDC/er obil 0il Corporation POST OFFICE POUCH 7-003 ANCHORAGE, ALASKA 99510 January 6, 1976 Atlantic Richfield Company P.. O..Box 360 Anchorage, Alaska 99510 NON-OBJECTION TO KUPARUK 22-11-12 WELL Dear Mr. Carr' Attached is a Drilling Permit Application submitted to the Alaska Division of Oil and Gas concerning the captioned wellsite. Please note that the well will be directionally drilled from a surface location in Section 23, TI IN, RI2E, UPM. The Alaska Oil and Gas Conservation Regulations (ll AAC 22.050) require the non-objection of an "affected operator" if deviated drilling operations are contemplated in a-quarter section directly or diagonally offsetting any quarter section-of said affeCted operator. Mobil's proposed operations will diagonally Offset the Arco-Exxon lease covering Section 26, TllN, R12E, UPM. If you do not object to the proposed operation, we would appreciate your sending a letter to the Division of Oil and Gas indicating your non- objection to the subject operation. Yours very/~ruly, R. W. PONFICK Land Representative RW.P :mw -Attachment , cc' Mr. Harry W.~..~Ugler Division o.£~'0il and Gas Mobil Oil Corporation December 31, 1975 P.O. BOX 5444 DENVER, COLORADO 80217 TELEPHONE (303) 572-3636 · State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99503 KUPARUK 22-11-12 NORTH SLOPE, ALASKA Dear Sir: Mobil Oil Corporation requests your approval for the drilling of the Kuparuk 22-11-12 well from a surface location approximately 1,742' from south line and 744' from west line of Section 23- TllN-R12E, Umiat Meridian, Alaska, in the State Lease No. ADL 47451. The well is planned to be/drilled directionally to'penetrate through Sadlerochit at ~~ from north line and ~' from east line of section 22-TllN-R12E, Umiat Meridian, Alaska, in the State Lease No. ADL 28263. It may be noted here that both leases Nos. ADL 47451 and ADL 28263 are held jointly by Mobil, Phillips and Socal. The surface location is selected to utilize the existing drilling pad. Application for Permit to Drill (form 10-401) with a check for $100 and the necessary attachments accompany this letter. /jl Attachments Yours very truly! W. G. Sole Area Engineer Alaska Producing Area 2;" SEITIE$ 16'00 D. "GATE 5" $ '~I?IES 1500 D. F VA L VE$ LJ [] l.i ' BOTTOm4 U L_I LJ DJ--Ti 1500 2 -' /?,4. 4F$' ON CHOKE MANIFO£D NOTE ' THIS IS A SCHEMA TIC SKETCH AND NOT A DIMENSIONAl DRAWING. UNIT TO BE ASSEMBLED, MOUNTED ON H BEAM SKIDS AND TESTED TO 5000 PSI. I. 5" X 2" FLANGED CROSS 2. 5" X 2" STUDDED CROSS' $. 2 " FI A NGED GA TE VALVE 4. $" FLANGED GATE VALVE 5. 2" ADJUSTABLE CHOKE FLANGED G. 2" POS! T/VE CHOKE Ft ANGED 7. DOUBLE STUDDED ADAPTER TO SWACO I0,000 PSI CHOKE 8. COMMON RESET REt IEF VALVE TYPE B 9. 2" COMPANION FLANGE AND HIGH PRESSURE NIPPLE I0. 2" COMPANION FLANGE - SCREW II. 2 ' HP BUtt- PLUG 12. SPACER NIPPLES CONS/STING OF WELD FLANGE ~ 2" LINE PIPE. !$. 2" STUDDED ELBOWS 14. 5" COMPANION FLANGE SCREW OUTLE FIGURE 5 // j '.-. CERTIFICATE OF SURVEYOR ? 18 19 30' iiiSCALE: = IMILE I hereby certify that I am properly registered and licensed to practice land surveying in the State of Al(~ska and that this plat represents a location survey made by me or under my supervision, and that all dimensions and other details are correct. · · . . I ! I I 2O 29 32 IT. lIN. 'il, ION. D~-c. 3o- ?5' · NOTE': Date .... SURVEYOR , . LOCATT.ON pLAT KUPARUK 23-11-12 IS THE SURFACE LOCATION. PERHIT TO' DRTLL FTLED FOR KUPARUK 22-11-12, THE BOTTOM HOLE LOCATION. , ,, AS - SIA~,E O 'LOCATION No. 2 ALTERNATE KUPARUK 23-I I - 12 Located in SW I/4 PROTRACTED SEC 25, l'liN,R Surveyed for MOBIL OIL C©RR :., - - I 1~_ ~1. '- ' Surveyed F..M. LINDSEY LAND I~ HYDROGRAPHIC SURVEYORS 12502 West Northern Lights Doulovord Box 4-,JSl~ CHECK LIST FOR NEW WELL PERMITS Is the permit fee attached ................ Company /k/~b// Yes No Remarks Lease & Well No. Is well to be located in a defined pool ............... x~ Is a registered survey plat attached .... -. Is well located proper distance from property line ..... Is well located proper distance from other wells ...... ~ Is sufficient undedicated acreage available in this pool well to be deviated .......... operator the only affected party . . . Can permit be approved before ten-day wait ............. Does operator have a bond in force ................. /~ Is a conservation order needed .................. Is administrative approval needed ................. Is conductor string provided .................... Is enough cement used to circulate on conductor and surface .... "~ll cement tie in surface and intermediate or production strinms cement cover all known productive horizons ........ Will surface casing protect fresh water zones ......... Will all casing give adequate safety in collapse, tension & burst Does BOPE have sufficient pressure rating ............. ,, .... A?proval Recommended' Geo 1 ogy _E n 9 i..n e.e ri n~' TP,~q ~'!/~ HWK A/~q OKG HHH JAL~ LCS J CM Revised 1/15/75 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 APPENDIXi No Special'effort has been made to chronologically organize this category of information. LIBRARY TAPE CURVE SPECIFICATIONS Company Sohio Alaska Petroleum Well KuparUk ST 22-11-12 Field Prudhoe Bay . County,State North Slope~ Alaska Curve Name (Abbreviated) Standard Curve Name Logs Used Scale ,, CPM Counts Per Minute SP 0-100 K ,., Potassium ~ SP 0-10 ,, . UR Uranium SP - 25- 25 , , TH Thorium SP - 75- 25 , , , ,L _. ,._ .,. 2,0-1~-12 o '-' :4 o o r:¢ o 05 .1. 5.9R 37.96 ~57 ~ q 00 :) 7":-?''': ;.;'¥7~¥;;;'=¥"'7'~:~c':;?"'7"-":'"'"':' :;:': ................. .................. "~"';-'~":'~"~ .......... : ....... ~: ............. :~"; ......... ~-~701.90 5~i o~ P 06 ~7 73 3~ OP r~7~o flO 55.~'~ ~ 79 ~ ~. 6m F~, 7r~. ~ n 5~.~. 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(]0 5~,, q? 1,.7~ 19.96 36.70 ~7!0.0~ 5G.93 !.77 18.89 38.3~ ~7!~ .08 5F,. !. ~ !.68 19.29 37.11 '":~:":'rr:?'"'~"~?~::'~:¥~:~':'r"7'T"?'7[%E:=':~'"R "": '"'"~ '":~':~;:;::7~-=:':;;;;~;;'~F'' ::;E.;7"[:;;' -" ::;;;,~Fc;~"' "7~i(~C~ ~':::;T %. ..... ~?:? ::.~:': .......... -:':':'":'~'~"~':~:?~:.. ,~C~7'"::~::~' ~:"~ ~?-'??:::7~:7~'r::=' [-~'::~"~'~'~'~F*':'"*'*'":;'::" 7""~ - "7' "~ ..r[~"' ' ". .......... : .................. ..... ,:-,:::~,:-:: : 2 1'2 : 1: ~ 5 ~ ..................................................... :_: .......... ~,.2J,..,.. , ,: ...... -;. -.., :: r~Ytv. OO 5~. I.% ~.1~ .1 S.97 ~l.lq "77.?;~ ;~¥'?:'¥'~ "~:-:'"'~'?;:'":7:"~::';'"~T":"::-'"'"'*f;~~'2g''0`'7,'U'''''' ...... :....: ...::::: ...::...2 2 2. ;: :;, .::2. :~::.:.i::.;!..:i :..:.:. :.::.~i:~::....E.... :: .: .~ .....: :_.....:._ ... :f ~.:~: ..Z,;~. :~ ..~.. i.....:~.:. ,........ :........: .. :...._.::, ._._.......~....' ..::~.....~% ................. ::i:... ,.~L... _i....:....~.L. _:...:......: ......... ......~....._:.~,:....: ~ 7!.,~,. O0 59.75 2.~ ~0.17 38.~3 C-':::=;7 ;'~U;7/':;?:7"~7:'~'~;"~::"7:"-'::-'"~!"::~'; 77:":7-~'U'~;~"g-- ``::~:"```.``:```:::`::`:`2~::`;~:%~:~`"`:;2:`::,``~`:````.:`.:`::`::::`:~`~:``:`~````::```::~::i`.`::L``"`.:LL`,a`````:::``````````: ._:LL:....:._...L.:...:.2L::..:..__...;.........2Z: ................ ~. .......... :i...: ................. ::.....:::......: ....................................... 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L; ._....:_....: ............. ; ........ ' 7 ~7;2~. O0 5q,02 1.99 ~7.~ -'":"-"'"-?~-~":-':-~?~:';-7-=~:r;,':': --- 7" "~' ~;" ?: "-~'~ 7 ": .............. ':"~'" ;-"-E¥ ....................... ~ .................. ~'" ................ .... ........... ........................ .......... ~,7;7%. O0 '52. F,P 2.0~ 15.79 SO ~0 ~La~KA 872.%.,50 51.65 1.90 15.49 39.4-2 ...... ~5 ,, :'2. ~ ~ ~7.9~ . .......... 872~. 5'" ~ , d 52 50 ~,~1 15,9~ ~0.85 `:y~`F`~:=:::;~:~;:;~;:~::~?:7:~::;::V~:C~`~`:~:~;~:;{C:,~:`~J?:~?`7:`~:::%;?`::~:~F;~:`~``T`7~`~:~S:~ ;F-::'' ':"'E;:::.=-' "::"':' '"~ ............. :T'"' ............. : R727.50 55.G0 1,52 13.95 q7.52 872a.50 5,-~. Sq. I.&S !~.5t ~1.35 P~729.50 5~,60 1.6B 1%.7~ q3.57 ~7~ ..... 873],50 5G,75 1.72 17.5~ 38.07 ':':;?:7'C:'~:F~;~'i;$F";:;':j?;~?S"~7~:?~?":'%:~:;;); '"~z ?~'5;~;~;:~7 ':7~?~ FT-%"""::T~::; '"' '~; "7' ;S" :: 7::?:'"" ~'~:7'~TS?':'TT':;''~'" "':" "=':-""};"-"-~'"S-'":" '2 87.~ 50 5~,~° 2 ~0 1~ xO q2.46 %~:~`:~: ~` ~:~2~:~::~ ~(;~;~:: ?~ ~:~:~}~::~:~~?~7:?~?~`F~`~%~TF`~T??9T:F::::;%;~]~=??7~``~`:~;~``~?;`=:?~`~`~7~7```=::=;~`~::`m``}:`9r`'.`:=~`?``T`r~``F`~*````m-`~```~:``~``:~`~S~``~:`````~`7;~`:`"`~-:`~''>:~:~ }. :~::;- ~. ~:~}~ ~ :~: : .- ~:.~ ~:~:~ ~ (:: -~ ~ ~ ~ .: ;.. ......................................................................... ~ ================================================================================================== .......... ::: :: ::_._.::_:::._.:.:::: .:::._..: :....: ,:,,.....:,.....__..:::.::.,: .::....: :........,::._..: :...:..: ,~ . < ~ :, ~-. ~ I,~ =================================== ~I::;S'7%~t~*i:::""::'~:':'%':'"Tm;T:~::"?'F:;:":~{' "~]::F'%':'t--'"Y':-* "?i~":?"-{{: !:::~;;i"~'"'":';;:'F:":":O'~ ]~:'?-']':'""'~['%ilir:'"-':']~;:""~ ~ i, ~.0 "77"'"':%-"%:"F:'-;: ~ ~ ¢'*?~'*'""~';~ ?"- ................................................................................................................................ .S Z: S :.;: :Z.::: .:,:::.2Z::,;:::: :::::,::L: ::~2: i! :,_:.::::.:.: ,,.:: ::::2;:.;:%: ::, ::::: ,: :i:, 2:,:::,.,:., ,,, ,. :,: A: ....,.. ::._.__.,:.:_....=S. ................. ., ._...::,...,..:,=._...,.Z,,LSL.,,_.,: ............. .... =,:S_._,, .......... : ...................... : ........... ~:7~q.. 50 ~$8,~ 2.01 17.85 37,06 <.:: :.._..::i .2Z :Z ::_ ::: .: .: _. _:. ::.:.:: .: :2 :::. _:: ::i:: S :: ..: ::._ ..-S::: .: :z:;s.A.:;,::..:,:, ,.::,S :, :2::...~. i .:, .. ,. ,!,.-,,.,,..,. ,,.- ,.,: .-: ...,.. :: .::-.--.:: ....... :-:, :.--: ............ ~,: L SiL- i.,.:,.;.,...,:,,,...,..-: ......... : L....,:..,.., ....~. ........... 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L:......:::..::.:<~,.:.._: ..................... ~75~,~ O0 59 lq 1 7~ 19 ~7 BT' O~ B755 O0 59 '~'~ P 03 18 5P .................................... 375~,00 Sn.26 2,10 tg,~ ~,77 ':: ?::?::~ff~ ============================ `:~i:~::iJ:~::~:~:~:``~`~:::~::&~:~::::::::~:~`~`:::i~`:~:~:`~:~``:`:~::;::<<:::~;::`~:<~L~`"~::":~"::~:~:~i:~`L~`" i,::.:::L.:~,;:.,,.:Z,,,,.,.,,:,::.,,_.Li<...,:L..,.:::,.. :,,:L,.,..,::s..,,i ~757.00 fig.~9 2.07 17.12 ~0,57 ::: ~:~::: ::i: :::i~: :.:: ~:~:: ~: L ::~ ~:~:: :,::::::::: ::L?:::: :,,;:: ::: ::: ::: :,.: ::: :; Z: i ,,:::::: :._.::: ,~:: ;.,..:_::,i .. :. ,:,: :,,:,.:: :: .:,: :L,._,,.~,: :...i:: :._:: ,,:: L.<.: :.,.,;.:,,,.,:.: .:, :: .. _: :: :_._: .:,~,_.-..~ :,,,,,.,.,: .............. 875a.00 5q, q. 9 T.B~ 1, B.O~ ~9.B7 875q.00 59.!q 2.09 1,.6,8~ ~0. ~0 7T:TT::~7?TT'":~:~Ti:;~'T;;;:"T:iTT?; ::~ :.~;;%.:;~.~-~/~ ::~ .~ ::: :.'::'~:~:~:~.:~ ~ :: ::':::~::: :t '::~ ~ :~ ~ ":~:~ ;; :fT~F:: T: '"'F:~T'Y?"::':::?T:TE?:' '"'?;'-~::: ''-::_. :~T7'7:" :'7'?"FF'"?T: ~ ~;.:~0 _:: :T'"'7)T ":'?'"'-'~7'''?'':~ 0 e':,..-~ Y'-'::]~'"~ :T" "" ........... : ........................ ~.:.~,~:,;:..i.i~:..,L.X,~;.fJ: 7.~Lf~; .~;~:....;;:cL:tc:::.t;t:cf:..!!:&::i:k L:~&CL.t.,<tt~::.:::f.b.:..:.:k.:_.,,.:::L:..L::,..:.:.:...: :..:.:.....:.......L ;.t ,.....& & :...~..:.:.:.:...-.:.......: .~.--::::...::.:-..... i& ....~ L.........: __...~..... :.L....;2: .......................... 8760.00 ~1.05 ~.~ 17.28 -'~?:~::s~'~sm' ;~';~v :; ~-~:~ ~v~ ~qq"'l'~S'~':' Za~'~q;~'?:C~ 7~":'""~% ?'~ ~'-;:'~'z~:~v 'Y"'::] '~:":'7:": ~?]:- '7~"'~'"~'"'~'"~":":'~'~ ~"T %' "2~]'i]T; '~-:r'V" ::":'7':~"'Y':;~':'''': ........... 7-''~':;~''~ ..................................................................................................................................... q7al., O0 61.,97 1,95 21 .P9 .......................... ~:~9,00 60 55 2 ]5 1~ 61 ..... ~ ~ · ,~ 76 3 B7G~.O0 60,3 876~.00 a o 9 87,..¢, O0 5 o% 87G7o00 39o': : :B76a.,qO ?~. 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LIS TAPE VERIFICATION LISTING LVP 009.H03 VERIFICATION LISTING ** REEL HEADER SERVICE NAME :SERVIC DATE :81/08/11 ORIGIN : REEL NAME :REEL ID CONTINUATION ~ :01 PREVIOUS REEL COMMENTS :REEL COMMENTS ** TAPE HEADER SERVICE NAME :SERVIC DATE :81/08/11 ORIGIN :1070 TAPE NAME :62045 CONTINUATION # :01 PREVIOUS TAPE COMMENTS :TAPE COMMENTS EOF ** FILE HEADER FILE NAME :SERVIC.O0! SERVICE NAME VERSION # : DATE : MAXIMbM LENGTH : 1024 FILE TYPE PREVIOUS FILE : ** iNFOrMATION RECORDS MNEM CONTENTS CN WN : FN : RANG: TOWN: SECT: COON: STAT: CTRY: SOHIO PLTROLEUM CO. KUPARUK ST 22-11-12 PRUDHOE BAY RANGE TOWNSHIP SECTION N. ShOPE ALASKA USA CONTENTS PRES~ NEDiT4F RECORD TYPE 047 ** RECORO TYPE 047 ** UNIT TYPE CATE SIZE CODE 000 000 O20 065 000 000 020 0~5 000 000 012 065 000 000 005 065 000 000 008 065 000 000 007 065 000 000 00~ 065 000 000 006 065 000 000 004 0~5 UNIT TYPE CAT~ S~ZE CODE uO0 000 007 065 LVP 009.H03 VERIFICATION LISTING PAGE 2 ** RECORD TYPE 047 ** ** DATA FORMAT ENTRY BLOCKS RECORD TYPE SIZE REPR CODE 4 1 66 8 4 73 9 4 65 0 1 66 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT API ID ORDER $ DEPT FT SIGM TOT CO FSIG TOT TRAT TOT NTDT TOT CPS FTDT TDT CPS GR TDT GAPI BACK TDT CPS FBAC TDT CPS GSF TOT AP LOG TYP 0 0 4 0 0 4 0 0 0 3 0 0 0 APl API FILE CLASS MOD NO, 0 0 0 4 1 0 0 4 0 0 0 4 I 0 0 4 0 0 0 4 0 0 0 4 32 0 0 4 0 0 0 4 0 0 0 4 0 0 0 4 DATA DEPT 10117.000 SIGM NTDT 411.500 FTDT FBAC 72.188 GSF DEPT 10100.000 NTDT 53.375 FTDT FBAC 56,469 GSF DEPT I0000.000 SIGM NTDT 302,250 FTDT FBAC 74.625 GSF DEPT 9900,000 NTDT 440 500 FTDT FBAC 137:125 GSF DEPT 9800.000 SZGM NTDT 472 000 FTDT FBAC 87:188 GSF DEPT 9700.000 SIGM NTDT 721,500 FTOT FBAC 123.438 GSF DEPT 9616.000 $IGM NTDT 83B.500 FSAC 134.000 -99 -99 l 2 25 2 15 1 28 27 -99 -99 9,250 FSIG -999.250 9.250 GR -999,250 1.731 7.484 FSIG 22,344 2.268 GR 14.750 3.000 0,672 FSIG 16,297 2.000 GR 64.813 1.731 1.031 F$IG 18.938 0,125 GR 39.938 1.731 8,391 FSIG 15,023 0,750 GR 22,219 1.731 3,367 FSIG 37.781 1.500 GR 67.188 1.000 9.250 FSIG -999.250 9,250 GR -999,250 0.577 ENTRY 60 .lin 0 PROCESS bEVEL 0 0 0 0 0 0 0 0 0 0 TRAT BACK TRAT BACK TRAT BACK TRAT BACK TRAT BACK TRAT BACK TRAT BACK SAMPLE 1 ! 1 ! REPR CODE ~8 68 68 -999.250 357.000 1.854 297.750 2.201 348.500 2.613 385,250 2.13'7 370.500 4 922 396:500 -999,250 403.250 LYP 009.H03 VERIFICATION LISTING PAGE 3 ** FILE TRAILER FILE NAME ;SERVIC.O0! SERVICE NAME : VERSION # DATE : MAXIMUM LENGTH : 1024 FILE TYPE NEXT FILE NAME ** FILE HEADER ** FILE NAME :SERVIC,O02 SERVICE NAME : VERSION # : DATE : MAXIMUM LENGTH : 1024 FILE TYPE : PREVIOUS FILE ; ** INFORMATION RECORDS MNE~ CONTENTS UNIT TYPE CATE SIZE CODE PRES: NEDiT4F ** RECORD TYPE 047 ** 000 000 007 065 ** RECORO TYPE 047 RECORD TYPE 047 ** ** DATA FORMAT RECORD ** ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 4 1 66 1 8 4 73 60 9 4 65 .lin 0 1 66 0 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT APl AP1 APl API FILE SIZE PROCESS SAMPLE REPR ID ORDER ~ LOG TYPE CLASS MOD NO. LEVEL CODE DEPT FT 0 0 0 0 0 4 0 SIGH TDT CU 0 40 1 0 0 4 0 FSIG TDT 0 0 0 0 0 4 0 TRA%' TDT 0 ~2 i 0 0 4 0 NTDT TDT CPS 0 0 0 0 0 4 0 FTDT YDT CPS 0 0 0 0 0 4 0 GR TDT GAPI 0 31 32 0 0 4 0 SACK TDT CPS 0 0 0 0 0 4 0 68 68 68 LVP 009,H03 VERIFICATION LISTING PAGE 4 FBAC TDT CPS 0 GSF TDT 0 NTDT 9 9:250 FTDT FBAC -999'250 GSF - . 50 -999,250 F$IG DEPT 10100.000 SIGH NTDT 16.953 FTDT FBAC 24.828 GSF -31.594 2.268 3.000 F$IG GR DEPT 10000,000 SiGH NTDT 422.000 FTDT FBAC 88.813 GSF 1~.625 252.000 1.73! F$IG GR DEPT 9900.000 SIGH NTDT 345,750 FTDT FBAC 147.750 GSF 22.563 150.125 1,731 F$IG DEPT 9800,000 SIGN NTD~ 495,500 FTDT FBAC 92,625 GSF 18.391 280.750 1o731 F$IG GR DEPT 9700.000 SIGH NTDT 814.500 FTDT FBAC 111,500 G$F 39.719 271.500 1.000 F$IG DEPT 9636.000 SIG~ NTDT -999,250 FTDT FBAC -999.250 GSF -999,250 -999,250 -999,250 F$IG GR ** FILE TRAILER FILE NAME :$ERVIC.O02 SERVICE NAME VERSION # DATE : MAXIMUM LENGTH : 1024 FILE TYPE NEXT FILE NAME EOF ** FILE HEADER FILE NA~E :S£RVIC.O03 SERVICE NAME VERSION ~ DATE : MAXIMUM LENGTH : 1024 FILE TYPE PREVIOUS FILE : 2, 94 2 344 16,29~ 43.5O 18.938 52,906 15.023 35.719 37 '999.250 '999.250 TRAT BACK TRAT BACK TRAT BACK TRAT BACK TRAT BACK TRAT BACK TRAT BACK ! 68 -9 . 50 1~6.375 2 559 1.827 288.000 2 225 3.961 302.250 4 648 -999:250 LVP 009,H03 VERIFICATION LISTING PAGE 5 ** INFORMATION RECORDS ** MNEM CONTENTS .... ~...m... PRES: NEDIT4F ** RECORD TYPE 047 ** RECORD TYPE 047 ** RECORD TYPE 047 ** UNIT TYPE DO0 CATE 000 SIZE 007 CODE 065 ** DATA FORMAT ENTRY BLOCKS RECORD TYPE 4 8 9 0 SIZE REPR CODE 1 66 4 73 4 65 1 66 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT ID ORDER # DEPT FT SIGM TDT CU FSIG TDT TRAT TOT NTDT TDT CPS FTDT TDT CPS GR TDT GAPI BACK TOT CPS FBAC TDT CPS GSF TDT LOG TYPE 0 0 0 4O 0 0 0 42 0 0 0 0 0 31 0 0 0 0 0 0 API API FILE CLASS MOD NO, 0 0 0 ! 0 0 0 0 0 I 0 0 0 0 0 0 0 0 32 0 0 0 0 0 0 0 0 0 0 0 ENTRY ! 6O .lIN 0 SIZE PROCESS SAMPLE LEVEL 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 REPR CODE 68 68 6B 68 68 68 68 68 68 68 ** DATA ** DEPT 1~107,500 SIGM NTDT 999,250 FTDT FBAC -999,250 GSF DEPT 10100.000 SiGM NTDT 20.859 FTDT FBAC 36,500 GSf DEPT 10000,000 SIGM NTDT 445.000 FTDT FBAC 80,875 GSM DEPT 9900,000 $IGM NTDT 431,250 FTDT FBAC 124,438 GSF -999,250 FSIG -999.250 GR -999,250 -31,594 FSIG 9.438 GR 0.577 i8 231 2 25 .~25 FSIG .000 GR 1.731 1,625 FSIG 5,750 GR 1,731 -0,~43 TRAT -999,250 BACK -218.375 TRAT 29,469 BACK 14,359 TRAT 42,000 BACK 17.031 TRAT 64.375 BACK -999.250 -999,250 025 2,154 287.250 2.416 318,750 LVP 009.H03 VERIFICATION LISTING PAGE 6 DEPT NTOT FBAC DEPT NTDT FBAC DEPT NTDT FBAC 9800,000 SIGH 502.250 FTDT 90.813 18.391 FSIG 285.000 GR 1,73! 13.539 TRAT 47.688 BACK 2.521 312.750 voo.ooo 831,000 FTDT 266.250 GR :063 BACK 326 000 94,063 9642,500 SIGH 797,000 FTOT 115,312 GSF ** FILE TRAILER ** FILE NAME :SERVIC.O03 SERVICE NAME : VERSION # ; DATE : MAXIMUM LENGTH : 1024 FILE TYPE : NEXT FILE NAME : 46 719 FSIG 296:750 GR 1,000 EOF ** FILE HEADER ** FILE NAME :SERVIC,004 SERVICE NAME VERSION # DATE : MAXIMUM LENGTH : 1024 FILE ~YPE : PREVIOUS FILE : ** INFORMATION RECORDS ** RECORD TYPE 047 ** ** RECORD TYPE 047 ** ** RECORD TYPE 047 ** MNEM CONTENTS SIZE REPR CODE 4 73 ~ 65 ! 66 PRES: NED£T4F 35,312 TRAT 81,250 BACK ** DATA FORMAT RECORD ** ENTRY BLOCKS TYPE 4 9 0 5,414 345,250 UNIT TYPE CATE SIZE CODE UO0 000 007 065 ENTRY ! 60 ,lin 0 LVP 009.H03 VERIFICATION LISTING PAGE 7 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT API API ID ORDER # LOG TYPE DEPT FT 0 0 SIGN TOT CU 0 40 FSIG TDT 0 0 TRAT TDT 0 42 NTDT TDT CPS 0 0 FTDT TDT CPS 0 0 GR TOT GAPI 0 BACK TDT CPS 0 0 FBAC TDT CPS 0 0 GMF TDT 0 0 DATA DEPT i0117,000 SIGN -999.250 NTDT -999,250 FTDT -999.250 FBAC -999,250 GSF -999,250 DEPT 10100,000 SIGM 5 035 NTDT 48,625 FTDT 2!:984 FBAC 53,563 GSF 3.000 DEPT 10000 000 SIGN !6 047 NTDT 241:125 FTOT 107:188 FBAC 77,500 GSF 1,731 DEPT 9900,000 SIGN 22.469 NTDT 490,500 FTDT 259'000 FBAC 134.250 GSF 1.731 DEPT 9800 000 SIGM 17.609 NTDT 503:000 FTDT 251'375 FBAC 89' 9]8 GSF 1,731 DEPT 9700 000 SiGN 36. 312 NTDT 799:000 FTOT 24~.250 FBAC 130,625 GSF !.000 DEPT 9616,000 SiGN 49.469 NTDT -999.250 FTDT -999,250 FBAC -999.250 GSF '999,250 ** FILE TRAILER FILE NAME :SERVIC.O04 SERVICE NAME VERSION # DATE : MAXIMUM LENGTH I 1024 FILE TYPE : NEXT FILE NAME API AP1 FILE SIZE PROCESS CLASS MOD NO. LEVEL 0 0 0 4 0 1 0 0 4 0 0 0 0 4 0 ! 0 0 4 0 0 0 0 4 0 0 0 0 4 0 32 0 0 4 0 0 0 0 4 0 0 0 0 4 0 0 0 0 4 0 FSIG GR FSIG GR FSIG GR FSIG GR FSIG GR FSIG GR FSIG GR 13.445 -0.121 15.961 -0.121 16 906 86:938 20,516 94,438 13.891 93'250 33.656 119.875 50.531 160.500 TRAT BACK TRAT BACK TRAT BACK TRAT BACK TRAT BACK TRAT BACK TRAT BACK SAMPLE REPR CODE 68 68 68 68 68 68 68 68 68 2 432 -999:250 205 3 086 347:750 2.053 381.500 2 367 371:250 4 434 4 223 LVP 009.H03 VERIFICATION LISTING PAGE ** FILE HEADER FILE NAME :SERVIC.O05 SERVICE NAME : VERSION # DATE : MAXIMUM LENGTH : 1024 FILE TYPE PREVIOUS FILE ** INFORMATION RECORDS MNEM CONTENTS PRES: NEDiT4F ** RECORD TYPE 047 ** RECORD TYPE 047 ** RECORD TYPE 047 UNIT TYPE CATE SIZE CODE 000 000 007 065 ** DATA FORMAT RECORD ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 4 8 4 73 60 9 4 65 .lin 0 1 66 0 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT API API API API FILE SIZE PROCESS SAMPLE REPR ID ORDER ~ bOG TYPE CLASS MOD NO. LEVEL CODE DEPT FT 0 0 SIGM TOT CU 0 40 FSIG TOT 0 0 TRAT TDT 0 42 NTDT TOT CPS 0 0 FTDT TDT CPS 0 0 GR TDT GAPI 0 31 BACK TOT CPS 0 0 FBAC TDT CPS 0 0 GSF TOT 0 0 0 0 0 4 1 0 0 4 0 0 0 4 I 0 0 4 0 0 0 4 0 0 0 4 32 0 0 4 0 0 0 4 0 0 0 4 0 0 0 4 68 ~8 68 6B 68 68 68 68 68 ** DATA ** DEPT NTDT FBAC 10117.000 SlGM ~999,250 FTDT 999,250 GS~ DEPT 10100,000 SiGM -999.250 FSIG -999.250 GR -999,250 17,063 FSIG 46.906 TRAT '0.121 BACK 16.219 TRAT -999.250 -999.250 1.704 bVP O09.H03 VERIFICATION LISTING PAGE 9 NTDT 244,000 FTDI FBAC 77'500 148.250 GR i.731 DEPT 10000,000 SIGM NTDT 365.750 FTDT FBAC 84.375 GSF 17.281 FSIG 199,500 GR 1.731 DEPT NTDT FBAC 9900.000 SlGM 386'000 FTDT 141.250 GSF 21,219 FSIG 248,625 GR 1.731 DEPT NTDT 9800,000 $IGM 450,500 FTDT 97,250 GSF 17.813 FSlG 261.750 GR 1.731 NTDT FBAC 9700.000 SlGM 790'500 FTDT 120,750 GSF 38.938 FSlG 251.750 GR 1.000 DEPT 9630.000 SIGN NTDT .-999,250 FTDT FBAC 999.250 GSF -999.250 FSlG -999.250 GR -999.250 *~ FILE TRAILER FILE NAME :SERVIC.005 SERVICE NAME VERSION # DATE : MAXIMUM LENGTH : 1024 FILE TYPE NEXT FILE NAME $* TAPE TRAILER SERVICE NAME :SERVIC DATE :81/08/11 ORIGIN :1070 TAPE NA~E :62045 CONTINUATION # NEXT TAPE NAME COMMENTS :TAPE COMMENTS ** REEL TRAILER *~ SERVICE NAME :SERV'IC DATE :81/08/11 ORIGIN : REEL NAME :REEL ID CONTINUATION # :01 NEXT REEL NAME : COMMENTS :REEL COMMENTS -0.121 BACK 19.344 TRAT 133.375 BACK 16.500 TRAT 97,312 BACK 13.773 TRAT 112.000 BACK 32.875 TRAT 134.500 BACK 39,250 TRAT -999.250 BACK 319.250 2 2, 38 376.250 2 51~ 2.244 400,250 4.379 426.000 -999.250 -999.250 DVP 009.H03 VERIFICATION LISTING PAGE lO ********************** ~ll,~ TYP~ ~R~VI~!!S ~TL~ : IIII ImllIII~ IIl~ till Illl tlii 000 OhO 013 065 OhO 000 012 065 nOO nO0 OO4 06~ 0an ~00 004 000 000 On2 065 00o OhO 00~ 0~ OOn 000 006 065 OhO 000 On4 0~5 7 ~ = 13.)75"' S{]~Fa('j'E. ~r') 272~ VT fLUID LMVEL = ******************************************************************************** , ~N~u D ~RV'T t"tF CU CPS ~U SI~ PS MTDT ?R~T WT~T WT~T MT~T ~T~T ~TnT ~E~T WTmT ~ ,~5g R~CK ~77,37~n ~ICt' ~7~.7K~0 31.4063 g~CK 1.9~ 7500 ~IC~ 15~.nRa4 g99.~500 -qgq.?.O0 -099.~5~0 2~.3770 20,703! 18 P242 135.4034 73.7559 q~.5000 23.7500 12A.3477 23.5547 95.~I95 2~.1~7% !,15.R7sn 2n.45tl ~STG ~c rSIG PRAC FR~C FBAC FM~C rRAC WST~ ~STG ~R~C rSTG ~C -gqa.25oo -~9q.75oo -~9.25:o'0 -~9~.~5~o -o9~ ~5o0 17.9949 22,93~0 ~7.3750 40.~313 16,6934 4~,7705 1,~,940~ 46.231a 17.75~0 ~.7520 20,1816 20.3418 40.9590 20.37~.1 47.89~6 5~,0~9 !7.1562 39.46R8 16.~175 43.9750 16.7344 5!.~7K0 ~TD? 790.0~6q mTr, T ~TDT -O90 75n~) ~TPT MTDT -o9o ~500 ~TD? -o99.75~0 -99o.7500 :~o.~r,c sT,:,' ~RTGTN :0on0 ~1.a~44 ,!~ " 'J. 4q' OOO0 37.5000 1,56.F7~ ~ , 3~.4063 99.7500 -999,~500 -q99.~$oo -999.~500