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Home My WebLink About167-057 0 III RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION NOV 3 0 2017 WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑✓ , Suspended❑ lb.WelIAl ((ILP 20AAc 25.105 20AAc 25.110 Development ❑� Exploratory ❑ GINJ ❑ WINJ ❑ WAG❑ WDSPL❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number/ Sundry: Hilcorp Alaska, LLC Aband.:' 9/26/2017 . 167-057/317-173 . 3.Address: 7. Date Spudded: 15.API Number: 3800 Centerpoint Drive, Suite 1400,Anchorage,AK 99503 October 5, 1967 50-733-20046-00-00 , 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 2383'FSL, 1368'FEL, Sec 13,T10N, R12W, SM,AK December 22, 1967 Granite Pt St 11-24 Top of Productive Interval: 9. Ref Elevations: KB: 115' 17. Field/Pool(s): Granite Point Field N/A GL: 0 BF: 55.3' Middle Kenai Oil Pool . Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 76'FNL,281'FWL, Sec 24,T1 ON, R12W, SM,AK 8,006'MD/7,418'TVD ADL018761 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 263398 y- 2544542 Zone- 4 11,800'MD/11,068'TVD N/A TPI: x- y- Zone- 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 262256 y- 2541597 Zone- 4 N/A N/A 5. Directional or Inclination Survey: Yes U(attached) No ❑✓ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 75' (ft MSL) 8,006'MD/7,418'TVD 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance,dipmeter,formation tester,temperature,cement evaluation, casing collar locator,jewelry, and perforation record. Acronyms may be used.Attach a separate page if necessary N/A SCANNED JAN 3 18 p Z. 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT CASING GRADE FT TOP BOTTOM TOP BOTTOM PULLED 18" 71# B Surface 638' Surface 633' 22" 800 sx 13-3/8" 61# J-55 Surface 4,030' Surface 3,796' 16" 1900 sx 9-5;8" 40/47# N80/S95 Surface 8,006' Surface 7,418' 12-1/4" 515 sx 24. Open to production or injection? Yes ❑ No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation Size SIZE DEPTH SET(MD) PACKER SET(MD/TVD) and Number; Date Perfd): N/A N/A N/A iFr/ * o°Na'1, 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. "--- Was hydraulic fracturing used during completion? Yes ❑ No ❑ 01 1z41Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED LL- 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): N/A N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period --*- Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate — Form 10-407 Revis d 5/ 017 42 `7.// CONTINUED ON PAGE 2 Submit ORIGINIAL l N /A��4'/<� .4 * hl, RBDMS 1, Ger U�) 2017 only • • 28.CORE DATA Conventional Core(s): Yes ❑ No Q Sidewall Cores: Yes ❑ No ❑✓ If Yes, list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� Permafrost-Top If yes,list intervals and formations tested,briefly summarizing test results. Permafrost-Base Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval N/A information, including reports,per 20 AAC 25.071. Formation at total depth: Tyonek 31. List of Attachments: Wellbore Schematic, P&A Reports. Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results,per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Paul Mazzolini Contact Name: Cody Dinger Authorized Title: Drilling Manager Contact Email: cdingertC7!hllcorp.com Authorized ?� ^/ ` I,/ Contact Phone: 777.8389 Signature: // Date: 1/011Z,0/7 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled 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.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item 1 a: 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 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange 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 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 19: Report the Division of Oil&Gas/Division of Mining Land and Water: Plan of Operations(LO/Region YY-123), Land Use Permit(LAS 12345), and/or Easement(ADL 123456)number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results, including, but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only H . Granite Point Platform 24 Well: Granite Pt St#11 Abandoned Schematic PTD: 167057 API: 50-733-20046-00 llileorn Alaska,LLC P&A on 9/26/17 RKB=114.75";43'Rig Floor to Wellhead CASING DETAIL FMC Unihead Size Wt Grade Conn ID Top Btm J I I 18" 70.59 B Ventura Surf 638' 13-3/8" 61 J-55 8rd 12.515" Surf 4,030' X X18„ 40 N-80 Butt 8.835" Surf 82' 43.5 N-80 Butt 8.755" 82' 123' tt:3 - C DV 40 N-80 Butt 8.835" 123' 1,955' Collar 9-5/8 40 N-80 LT&C 8.835" 1,955' 5,547' @2285' 40 S-95 ST&C 8.835" 5,547' 6,537' 43.5 5-95 ST&C 8.755" 6,537' 8,006'(KOP) 7" 29 P-110 X-Line 6.184" 9,963' 11,798' 4 i 1 TUBING DETAIL(FISH) 13-3/8" 3-1/2" 9.2 L-80 SC-BTC 3.992" 9,828' 10,699' 13-5/8(-440) Bad spot where screwed into csgafter JEWELRY DETAIL parting Tow 08,006, NO Depth Depth ID OD Item BOW @8,023' (MD) (TVD) Possible 8,028' 7,437' CIBP(Set for whipstock) Corrosion 250'-550' .1' _ &ti(,' , OBP8,028 1 9,440' 8,781' Top Cement Plug(11 BBLS)--9,440'-9,585' TOC rii 2 9,585' 8,924' HES EZ-SV Cement Retainer 9110' poor ry ,,, , 3 9,587' 8,926' Bottom Cement Plug(47 BBLS)--9,587'-11,165' bonding 1,4,17.1,' „,, . ,, Fish:Wash-pipe Shoe L=4.35',OD=8-1 2"-ID=7- ,v:-.;',111..,. 1 ??? 7-1/8" 8-1/2" 1/8„) ( / 21 4 9,828' 9,165' Top of tubing fish is @ 9,833',Top of WP @ 9828' Ghost Hole 5 9,836' 9,173' Otis"XO"Sliding Sleeve w/valve 9674'- ? g 6 10,480' 9,805' Otis"XO"Sliding Sleeve w/valve 10,288' 7 10,699' 10,019' 2.635" Otis"Q"Profile Nipple TOF 9,828' xo 4 ABANDONED PERFORATION DETAIL 5 Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Accum SPF Date Status Block cmt sqz 28 cuft of TOL @ \ 7 class"G".tested to 9,963' i. „ 9,765' 9,766' 9,103' 9,104' 1' 8 1/6/1968 5,000 psi. f 1, * C2 9,836' 9,866' 9,173' 9,203' 30' 4 1/10/1968 Perf f/Production 9-5/8" Pressure tested to 5,000 1' 9,950' 9,951' 9,285' 9,286' 1' 4 1/3/1968 psi,no break down C5 10,095' 10,130' 9,428' 9,462' 35' 4 1/10/1968 Perf f/Production C5 10,150' 10,240' 9,481' 9,570' 90' 4 1/10/1968 Perff/Production C6 10,315' 10,350' 9,643' 9,677' 35' 4 1/10/1968 Perf f/Production Pressure tested to 5,000 I 10,400' 10,401' 9,726' 9,727' 1' 4 1/3/1968 psi,no break down C7 10,535' 10,560' 9,858' 9,883' 25' 8 10/25/1968 Perf f/Production C7 10,580' 10,660' 9,902' 9,981' 80' 8 10/25/1968 Perff/Production " ." C7 10,675' 10,700' 9,995' 10,020' 25' 8 10/25/1968 Perff/Production Pressure tested to 5,000 Y txo 6 10,750' 10,751' 10,069' 10,070' 1' 4 1/2/1968 psi,no break down r� Isolated below retainer C9 11,135' 11,165' 10,442' 10,471' 30' 4 12/30/1967 @ 11,108' a - 7 1 FISH $' Item Top of tubing fish is @ 9,833',Top of WP @ 9828'. ('A .. .i »,.II 7" PBTD:9,440' TD:11,800' Hole and bad spots in casing from 9,772'to 9,838'. See morning reports for more detail. MAX HOLE ANGLE±252 Updated By:CJD 11/29/17 • • Hilcorp Energy Company Composite Report Well Name: GPF GP 11-24RD Field: County/State: ,Alaska (LAT/LONG): ;vation(RKB): API#: Spud Date: Job Name: 1711828P GP 11-24RD PreDrill Contractor AFE#: AFE$: 40M..1x1 6/11/2017 (Initial report)Skidded rig South then East from 22-13RD2 to 11-24. Laid derrick over in order to use crane while finishing skid with chain hoists-stowed jacking equipment.,Spotted choke and koomey houses,electrical bang box-hooked up all high pressure hoses to mud pump-installed all handrails and walkways-positioned racking matt. Cleaned and organized deck.,Held PJSM w/rig and crane crews,production,NOS(2)and WSM-insured casings were open to atmosphere. N/D dry hole tree-UD same. Cleaned corrosion and old emergency packing material from top of 9 5/8"x 13 3/8"packoff-pulled and replaced packoff WI fresh one. NOS reps tested packoff to 500 psi low 3500 psi high-installed 4 1/2"IF test plug w/drain hole.,Began N/U 13 5/8"5M BOPE. 6/12/2017 Finished N/U 13 5/8"5M BOP stack.,Raised and scoped out derrick securing all guy lines. Ran and connected koomey and circ lines to stack-positioned drill shack-mounted rig floor,wind walls,steps to drill shack and off side-hooked up remote control panel-set bang box in place at front of rig along w/test pump. Energized koomey unit and functioned all hyd components.,Changed brakes pads on draw works and functioned tested after mounting-all good,R/U floor w/ handing tools and tongs- M/U test equipment w/3 1/2"test jt-screwed into test sub and shell tested to 3500 psi.,Tested BOPE to 250 psi low 3500 psi high as per Sundry in accordance to AOGCC and Hilcorp requirements-performed successful koomey draw down test. Test witness waived by Mr.Regg at 2:02 PM 6/12/17.,R/D test equipment and pulled test plug.,M/U BHA#1 8 1/2"bit and scraper= 8.93'. TIH picking up 3 1/2"12.95#P-110 PH-6 workstring off deck- strapping,drifting and torqueinq to 6000 FPT. 938'in hole at report time. 6/13/2017 TIH w/8 1/2"bit&scraper picking up 3 1/2"12.95#P-110 PH-6 workstring off deck-strapping,drifting,torqueing to 6000 FPT. Ran in 290 jts=9,003'(PUW 126k SOW 78k). M/U safety valve and lined up to rev across shaker-closed pipe rams.,Reversed 1 hole volumes(655 bbls clean FIW)at 2.7 bpm 350 psi.,R/U and tested 9 5/8"casing to 2600 psi for 45 mins on chart w/no loss(9 5/8"X 13 3/8"annular pressure is 150 PSI©2600 PSI on 9 5/8"casing)- all good. Bled off pressure-R/D test equipment.,Started OOH UD 3 1/2"PH6 work string-0330 hrs worked MN Titon receiving kill string and hanger. 224 of 290 jts OOH at report time=2,052'. 0 fluid lost to well last 24 hrs. 6/14/2017 Finished POOH w/BHA#1 (8 1/2"bit&scraper)-laying down workstring. B/D bit&scraper-cleared rig floor.,Spotted and R/U Pollard ELine equipment. M/U GR/Sector Cement Bond Tool and TIH tagging at 9,248'(correlated to GP11-24_GR.las file)-logged from 9,248'to 7,248'in 9 5/8"40-43.5#casing(poor quality to no cement thru interval). POOH&B/D bond tool.,M/U PDS Multifinger Casing Caliper Tool(memory mode)and TIH to 9,220'-pulled log from 9,220' to surface. OOH at 1700 hrs-tool programed to close at 1736 hrs. RID ELine.,Laid out&strapped 3 1/2"9.2#L-80 BTC kill string after moving ELine unit-ran in open ended w/70 jts(2,187.81')-M/U hanger w/pup&landing jt(w/assistance from NOS)- PUW 26K SOW 26K.,Drained stack and landed hanger(EOT at 2,235.50')-ran in holdown pins-laid down landing jt and and set BPV.,Cleared rig floor of handling tools and tongs-rigged down floor. Scoped in and laid over derrick-moved pipe racking mat.,N/D BOPE-began prepping workover package for transpot to Dolly.,N/U dry hole tree. 6/15/2017 Finished N/U dry hole tree-tested hanger void to 800 psi low f/5 mins,5000 psi high f/15 mins. Pulled BPV and set 2-way check-shell tested tree to 600 psi low f/5 mins,5000 psi high f/15 mins. Pulled 2-way check and handed well back to production.,Organizing and cleaning W/O package in prep for move to Dolly Platform D-16RD well. Cleaned front end of rig tank,unstrung drill line onto spool,unbolted draw-works,moved driller shack,washed down carrier& derrick,washed down BOPE,cleaned out sand trap. Night crew will depart for Dolly Platform at 6 am while Day crew will load MN with 1st load of W/O equipment. This will be the last report on pre-drill AFE. • • Hilcorp Energy Company Composite Report Well Name: GPF GP 11-24RD Field: County/State: ,Alaska (LAT/LONG): evation(RKB): API#: Spud Date: 9/26/2017 Job Name: 1711828D GP 11-24RD Drilling Contractor Kuukpik 5 AFE#: AFE$: ,beta .. ,,.........:.:............................................................................. * .....,, ,,,.,,,, ...,<... . .. ::::.k.:::::::::.:::�. ,.:.:...� ...............:.1'............. ...x...........:..............,.............,.,.,.\\,...............................................x,...a..3.Y.......�\,.� ,...\a .........,..P..........................J'...,,,..............,x£b.\,........k..,.............f......................................,.a\,...:\.:.\.:.,..�.�.�.::�::.::.::.:c.::.::.::.::::.::.::.::.::.;:..:.+:.::.: 9/22/2017 Skid rig from 22-13&spot over well.Install storm clamps.stairs&landings.Connect service lines. 9/23/2017 Install Koomey landing,water tank landing.Move service lines for bridge stand.Lower bridge stand and upper bridge stand.Set catwalk and beaver slide.Pull rotary table.Pull riser spool out of;cellar.Assist with setting BPV.Prepare to nipple down tree.Begin working on flow line.;Secure cat walk stand and support complex.Hold PJSM.Nipple down tree.Install riser and gray lock.Nipple up BOPE.;Cont.to N/U BOPE.C/O upper rams to 2-7/8"X5"VBR's.N/U kill line manifold.Welding projects.;N/U Koomey lines&function BOPE.N/U flow line,flow box,&pollution pans. Install rotary table.Clean&clear rig floor. 9/24/2017 Install flow line to shakers.Hang service lines in sub.Clear and clean rig floor.R/U vacuum unit to sub.Fabricate new flow nipple.Organize and clean cellar area.;Organize and clean all areas of rig.Continue with miscellaneous welding projects.;Make up 4 1/2" test joint.Fill stack.Shell test at 2500 psi.Test BOPE at 250113500 H.and annular at250 U2500 H AOGCC(Jim Regg)waived witness of test on 9/22 at 14:20 hrs.;Changed out 1 ea. 2 1/8"annulus valve during BOPE test.UD 41/2"test joint.;M/U 31/2"test joint.Test upper pipe rams at 250113500 H,and annular at 250 U2500 H.UD 31/2"test joint.;Pull BPV.M/U <1,p, landing joint&RIH&engage hanger.BOLDS.Pull hanger to rig floor&LID landing joint.;R/U Weatherford to UD tubing.Breakout of hanger&UD same.;POOH &UD 70 jts 3-1/2"tubing from 2188'.;R/U Pollard E-Line&M/U Baker CIBP.;RIH with CIBP.;Wellhead pressures:20"=34 psi,13 3/8"=40 psi Fluid loss to well today:0 bbls.Total:0 bbls. Code 8: 0 hrs,Total:0 hrs Total Sept:12.5 hrs Metal recovered: 0 lbs.Total:0 lbs. 9/25/2017 Pollard e-line RIH with CIBP.Correlate on depth and set plua at 8.028'.POOH and R/D wire line unit.;Test casing at 1500 psi on chart for 30 minutes(good test). Pumped 5 bbls/bled off 4 bbls.;RIH picking up 14 joints of HWDP and 10 joints of CDS-40 drill pipe.;Service rig.Hold'kick while tripping'drill.;RIH picking up drill pipe.Picked up a total of 56 joints.;POOH standing back HWDP and drill pipe.;Clear rig floor.Pick up whip stock assembly.;M/U whipstock milling assembly AV as per Baker rep to 595'.Shallow hole test MWD(good).;RIH with whipstock&mills to 7,854'.;Orient whipstock to 48 Right.Set whipstock&shear as per Baker li rep.TOW-8,006'/BOW-8,023'.;Clean&clear floor.Prep for OBM displacement.;Wellhead pressures:20"=34 psi,13 3/8"=40 psi Fluid loss to well today:0 bbls.Total:0 bbls. Code 8: 0 hrs,Total:0 hrs Total Sept:12.5 hrs Metal recovered: 0 lbs.Total:0 lbs. 9/26/2017 Displace FIW to production at 5 BPM/380 psi.;Take on OBM from beam tank for pit volume and well displacement.;Displace well with OBM at 5 BPM/400 psi. Circulate and condition mud.;Establish SPRs&Begin milling window at 8,006',per Baker hand.DW 97K,ROT 105K,100 RPM,TQ 5K off bottom,TQ 6-10K on bottom,420 GPM 2050 PSI.;Mill window from 8,006'to 8,016',with 60%CMT,15%Metal,10%Coal,15%Claystone in returns.Continue milling window from V016 to bottom of window at 8,023'. Drill 20'of new hole in 5'.;increments due to fast ROP. Stop rotation and lowered pump rate,formation would hold 10K V 'VOB. Drill 20'of new hole,work mills through window cleaning up same. (Recovered 311 lbs metal).;Circ hole clean and condition for FIT.;Perform FIT to 12.5 0`)° EMW,charting same took 6 BBL to achieve 12.5 EMW and bled back 5 BBL.;Continue drilling new formation from 8,043'to 8,073'for a total of 50'of new hole W outside of window.at 2.5K WOB,90 ROP,425 GPM.2020 PSI SPP.;Rack back 1 stand to 7,982'.Circulate and condition mud prior to tripping out of hole for directional BHA,while polishing and drifting window.F/C&pump dry job.;POOH from 7,982'to 80'.Racked back HWDP.;UD Baker milling BHA from 80'.;Clean &clear floor.R/U Johnny wacker to flush stack.;Wellhead pressures:20"=20 psi,13 3/8"=110 psi Fluid loss to well today:0 bbls.Total:0 bbls. Code 8: 0 hrs,Total:0 hrs Total Sept:12.5 hrs Metal recovered: 311 lbs.Total:311 lbs. • OF TMJ 40,�\�yyy�,t, THE STATE Alaska Oil and Gas N"))11 ---.„ � � D,fA c k Conservation Commission �r riz �� 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 FALAS�� Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Stan GolisNNED iiiV ` i) Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Granite Point Field, Middle Kenai Oil Pool, Granite Pt St 11-24 Permit to Drill Number: 167-057 Sundry Number: 317-173 Dear Mr. Golis: 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. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration 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. Sincerely, /679/-644 _ Cathy . Foerster / Chair DATED this /l day of May, 2017. RBDMS 1,l/MAY 1 6 2017 • • RECEIVED STATE OF ALASKA MAY 01 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill 0 • Perforate New Pool ❑ Re-enter Susp Well 0 ' Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: '5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development 0. 167-057 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20046-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A - Will planned perforations require a spacing exception? Yes ❑ No 0 J Granite Pt St 11-24 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018761 • Granite Point Field/Middle Kenai Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,800 ' 11,071 ' 9,440 ' 8,780 • 2,821 psi 9,440 N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 638' 18" 638' 633' Surface 4,030' 13-3/8" 4,030' 3,796' 3,090 psi 1,540 psi Intermediate Production 10,086' 9-5/8" 10,086' ' 9,418' 5,750 psi 3,090 psi Liner 1,835' 7" 11,798' 11,069' 11,220 psi 8,510 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development 0 ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work. 6/1/2017 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended 0 • 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stan W.Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarlowe@hilcorp.com 11 Contact Phone:5907)283-1329 • Authorized Signature: C)to....4.••• Date: S/ t ' L? COMMISSION USE ONLY Conditions of approval: Notify Commission s that a representative may witness Sundry Number: 17- / 7S Plug Integrity ❑ BOP Test V. Mechanical Integrity Test ❑ Location Clearance ❑ l f—I c I t t>1q Other: 3CDC) rS� / 0 s-(- ( G - fo-- 4"-- c Y--- / Post Initial Injection MIT Req'd? Yes ❑ No ❑�Lr'/ Spacing Exception Required? Yes ❑ No Subsequent Form Required: p=„:--`f Ci 7 RBDMS w MAY 1 6 2017 APPROVED BY Approved by: ,d......._ COMMISSIONER THE COMMISSION Date: ,S— f/_./7 Ile4P s/2/R- .04, ,5/?/75-Li-17 O RIGINALlid Submn Form ane Form 10-403 Revised 4/2017 for 12 months from the date of approval. Attachments in Duplicate • • Well Work Prognosis Well: GP 11-24 Date: 04/07/2017 Hilcorp Alaska,LLG Well Name: GRANITE PT ST#11-24 API Number: 50-733-20046-00 (GP 11-24) Current Status: Suspended - Producer Leg: Leg#3 Estimated Start Date: June 01, 2017 Rig: Moncla 404& Kuukpik#5 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 167-057 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Monty Myers (907) 777-8431 (0) (907) 538-1168 (M) Current Bottom Hole Pressure: 3,463 psi @ 9,100'TVD 0.410 lbs/ft(7.88 ppg)based on SIBHP Maximum Expected BHP: 3,463 psi @ 9,100'TVD 0.410 lbs/ft(7.88 ppg)based on SIBHP Maximum Potential Surface Pressure: 2,821 psi Using 0.1 psi/ft gradient per 20AAC25.280(b)(4) Brief Well Summary GP 11-24 is a suspended C sands producer lugged back in September 1997. This workover will prepare the well for a side track. Last Casing Test: 09/30/1997 3000 psig against cement plug at 9,440' Procedure: Phase I Ntc 1. MIRU Rig. 0`I 2. Bleed down well and ND Wellhead 3. Pull and replace 9-5/8" by 13-3/8"hack-off assembly. 4. NU BOP and test to 250psi low4 sl high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 5. Monitor well to ensure it is static. 6. RIH with bit and scraper to±9,000', circulate clean. POOH. 7. POOH w/work-string 8. RU E-line and run caliper log from ±9,000' to surface. 9. Pressure Test casing to 2,500 psig for 30 minutes and chart. 10. RU e-line and RIH w/CIBP to ±8,500', ±5' above casing connection. POOH 11. RIH with ±2,000' of kill string 12. Set BPV, ND BOP, NU Dry Hole Tree and test. 13. Suspend operations / Use I! Out atr'ad1' '44u► 5 '.pegd� O'tf f ;ell/ ftef4ed f-0 r /'eG(r, l . c et (etA.ew flea b S�� 5-4;7Na ` `� • Well Work Prognosis Well: GP 11-24 Date: 04/07/2017 Hilcorp Alaska,LLC Phase II 1. Resume operations with Kuukpik#5 2. MIRU Kuukpik#5 3. Circulate well 4. ND Wellhead, NU BOP and test to 250psi low/3,500psi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 5. Monitor well to ensure it is static. r- 6. Circulate well and pull kill string 11 14. Swap well to OBM drilling fluid. 15. Mill 8-1/2" window and 20' of new formation. POOH and LD mills. � ***Remaining Procedure to be included on the Permit to Drill Sundry for the sidetrack*** General sequence of operations pertaining to drilling procedure: (informational only) 1. PU directional BHA and TIH to window. 2. Drill 8-1/2" hole to the C-7 sands. 3. Run/Cement/and cleanout 7" casing. 7 4. Swap to completion sundry. Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic Current 4. BOP Drawing—Moncla 404 5. Fluid Flow Diagrams—Moncla 404 6. BOP Drawing—Kuukpik 5 7. Fluid Flow Diagrams—Kuukpik 5 8. RWO Sundry Revision Change Form • 0 Granite Point Platform 11 SCHEMATIC Well: Granite Pt St#11-24 PTD: 167-057 API: 50-733-20046-00 Temporarily Suspended:9/30/97 Hilcorp Alaska,LLC RKB=114.75"; 43'Rig Floor to Wellhead FMC Unihead CASING DETAIL 4 Size Wt Grade Conn ID Top Btm ( 18" 70.59 B Ventura Surf 638' 13-3/8" 61 1-55 8rd 12.515" Surf 4,030' X -. 1 X 40 N-80 Butt 8.835" Surf 82' 43.5 N-80 Butt 8.755" 82' 123' :14, 9 5/8„ 40 N-80 Butt 8.835" 123' 1,955' •iy' 40 N-80 LT&C 8.835" 1,955' 5,547' 40 5-95 ST&C 8.835" 5,547' 6,537' DV 43.5 S-95 ST&C 8.755" 6,537' 10,086' Collar7" 29 P-110 X-Line 6.184" 9,963' 11,798' 7' TUBING DETAIL (FISH) nP.--`, 3-1/2" I 9.2 I L-80 I SC-BTC ] 3.992" j 9,828' 10,699' �j✓// Stiff' 2000 --i (2.0- r,;... Pra , s F JEWELRY DETAIL . . No Depth Depth ID OD Item 13-5/8(-440') (MD) (TVD) ( 1 9,440' 8,781' Top Cement Plug(11 BBLS)--9,440'-9,585' Bad spot where 2 9,585' 8,924' HES EZ-SV Cement Retainer screwed into csg I" Fish: 3 9,587' 8,926' Bottom Cement Plug(47 BBLS)--9,587'-11,165' after parting 10Fish:Wash-P P i e Shoe(1=4.35',OD=8-1/2"-ID=7- SCa ??? 7-1/8" 8-1/2" 1/8") Possible Corrosion v iq`1.i / 4 9,828' 9,165' Top of tubing fish is @ 9,833',Top of WP @ 9828' 250'-550' 5 9,836' 9,173' Otis"XO"Sliding Sleeve w/valve 6 10,480' 9,805' Otis"XO"Sliding Sleeve w/valve �. TOC @ 9110' . X74 7 10,699' 10,019' 2.635" Otis"Q"Profile Nipple : • poor bonding IA 2 `t5 ABANDONED PERFORATION DETAIL Ghost Hole Top Btm Top Btm Accum 9674'-10,288' 3 Zone (MD) (MD) (TVD) (TVD) FT SPF Date Status xo "t Block cmt sqz 28 cuft of TOF @ 9,828' 4 class"G".tested to 5,000 9,765' 9,766' 9,103' 9,104' 1' 8 1/6/1968 psi. 5 TOL @ 9,963' \ C2 9,836' 9,866' 9,173' 9,203' 30' 4 1/10/1968 Perf f/Production Pressure tested to 5,000 9,950' 9,951' 9,285' 9,286' 1' 4 1/3/1968 psi,no break down Z. C5 10,095' 10,130' 9,428' 9,462' 35' 4 1/10/1968 Perff/Production C5 10,150' 10,240' 9,481' 9,570' 90' 4 1/10/1968 Perff/Production C6 10,315' 10,350' 9,643' 9,677' 35' 4 1/10/1968 Perff/Production 4. <�9 Pressure tested to 5,000 � 10,400' 10401' 9,726' 9,727' 1' 4 1/3/1968 psi,no break down 9, C7 10,535' 10,560' 9,858' 9,883' 25' 8 10/25/1968 Perff/Production "r C7 10,580' 10,660' 9,902' 9,981' 80' 8 10/25/1968 Perff/Production i C7 10,675' 10,700' 9,995' 10,020' 25' 8 10/25/1968 Perf f/Production Pressure tested to 5,000 xo / 6 10,750' 10,751' 10,069' 10,070' 1' 4 1/2/1968 psi,no break down . Isolated below retainer C9 11,135' 11,165' 10,442' 10,471' 30' 4 12/30/1967 @ 11,108' Q. ll 7 ■ FISH i Item Top of tubing fish is @ 9,833',Top of WP @ 9828'. L Hole and bad spots in casing from 9,772'to 9,838'. See morning reports for more detail. PBTD=9,440' MAX HOLE ANGLE±25° Updated by RTE 03/16/17 n • • Granite Point Platform Well: Granite Pt St#11-24 PROPOSED PTD: 167-057 API: 50-733-20046-00 Hilcorn Alaska,LLC Temporarily Suspended:9/30/97 RKB=114.75";43'Rig Floor to Wellhead CASING DETAIL FMC Unihead Size Wt Grade Conn ID Top Btm j I I 18" 70.59 B Ventura Surf 638' 13-3/8" 61 J-55 8rd 12.515" Surf 4,030' X X 40 N-80 Butt 8.835" Surf 82' 18" 43.5 N-80 Butt 8.755" 82' 123' /1 n DV 9-5/8" 40 N-80 Butt 8.835" 123' 1,955' Collar 40 N-80 LT&C 8.835" 1,955' 5,547' @ 2285' 40 5-95 ST&C 8.835" 5,547' 6,537' 43.5 S-95 ST&C 8.755" 6,537' ±8,500'(KOP) 7" 29 P-110 X-Line 6.184" 9,963' 11,798' I li TUBING DETAIL(FISH) 13-3/8" 3 " 3-1/2" 9.2 L-80 SC-BTC 3.992" 9,828' 10,699' 13-5/8(-440') 4"'-----'y Bad spot where screwed into `„�� csgafter JEWELRY DETAIL parting No Depth Depth ID OD Item Possible (MD) (TVD) Corrosion CIBP±8,500 ±8,500' ±7,871' CIBP(Set for whipstock) 250'-550' _ - 1 9,440' 8,781' Top Cement Plug(11 BBLS)--9,440'-9,585' TOC(ii I 2 9,585' 8,924' HES EZ-SV Cement Retainer 910' poor P.,�. 1 , ,.-1 3 9,587' 8,926' Bottom Cement Plug(47 BBLS)--9,587'-11,165' bonding 1 Fish:Wash-pipe Shoe(L=4.35',OD=8-1/2"-ID=7- °t '''1F�tl,;,. ??7 7-1/8" 8-1/2" 1/8") Ifi-."` 2; 4 9,828' 9,165' Top of tubing fish is @ 9,833',Top of WP @ 9828' Ghost Hole .,,; #;a, -' 5 9,836' 9,173' Otis"XO"Sliding Sleeve w/valve •9674'- i*;' 4,,,-.0v 3 6 10,480' 9,805' Otis"XO"Sliding Sleeve w/valve 10,288' .... 4t. til 7 10,699' 10,019' 2.635" Otis"Q"Profile Nipple TOF a s { � 4 9,828' file ,, ABANDONED PERFORATION DETAIL * ' ^; . . 5 Top Btm Top Btm Accum k Zone FT Date Status . t (MD) (MD) (TVD) (TVD) SPF k 4..'};` Block cmt sqz 28 cuft of TOL @ > « s° class"G".tested to 9,963' , «+ 9,765' 9,766' 9,103' 9,104' 1' 8 1/6/1968 5,000 psi. 1 .4 .r A w/c 5, C2 9,836' 9,866' 9,173' 9,203' 30' 4 1/10/1968 Perff/Production }5/g Pressure tested to 5,000 9,950' 9,951' 9,285' 9,286' 1' 4 1/3/1968 psi,no break down CS 10,095' 10,130' 9,428' 9,462' 35' 4 1/10/1968 pp es CS 10,150' 10,240' 9,481' 9,570' 90' 4 1/10/1968 Perff/Production C6 10,315' 10,350' 9,643' 9,677' 35' 4 1/10/1968 Perff/Production Pressure tested to 5,000 j 10,400' 10,401' 9,726' 9,727' 1' 4 1/3/1968 psi,no break down C7 10,535' 10,560' 9,858' 9,883' 25' 8 10/25/1968 Perf f/Production a C7 10,580' 10,660' 9,902' 9,981' 80' 8 10/25/1968 Perf f/Production � C7 10,675' 10,700' 9,995' 10,020' 25' 8 10/25/1968 Perff/Production . a 6 Pressure tested to 5,000 10,750' 10,751' 10,069' 10,070' 1' 4 1/2/1968 psi,no break down Isolated below retainer ;� C9 11,135' 11,165' 10,442' 10,471' 30' 4 12/30/1967 @ 11,108' -} A al 7 '' FISH r*. a i., Item Top of tubing fish is @ 9,833',Top of WP @ 9828'. PBTD:9,440' TD:11,800' Hole and bad spots in casing from 9,772'to 9,838'. See morning reports for more detail. MAX HOLE ANGLE±25° Updated By:JLL 03/16/17 • • 11 Granite Point GPP 11-24 12/19/2016 nileorp:1.1a4a.1.1A: Granite Point NO TUBING HANGER IN 11-24 WELL 18X133/8X95/8 BHTA,CIW,external knockup 3 1/8 5M FE 01 n .1.. Valve,Swab,McEvoy-C, ��G�' 3 1/8 5M FE,HWO, r EE trim `• "' L _\ Valve,Master,McEvoy-C, -- -. 3 1/8 5M FE,HWO, EE trim Valve,Master,McEvoy-C, /0,-,:r= I 3 1/8 5M FE,HWO, (7 4 EE trim --- -1lr. Adapter,FMC-ASP,13 5/8 5M , ": API clamp X 3 1/8 5M,w/ ..,„.....--1P. Unihead,OCT type 2,13 5/8 5M API ,' 6.990"extended neck pocket hub top X 13 3/8 BTC casing bottom, ) w/2-2"LPO on lower section,2-2 �'' 1/16 5M SSO on upper section,IP internal lockpin assy Packoff is not seated in e/'`p l .:1) wellhead _. t -Valve,-GOT-20' Valve,G T-20,2 1/16 5M R 4 e ,, i , gam* HWO,AA trim k 0 "may'f� �,`'� Starting head,OCT, - + 1 i., 21 1/4 2M Hub x 24 Y.1M f 1 Valve,OCT-20,2"LPO,HWO, Hub w/2-2"LPO,prepped f/ ! . AA trim 18"EN hanger ,yam 0,., 6 , Conductor housing, '' j 1 } k_ 24 Y.1M Hub X �')— 24"Buttweld , 1 rI _ ( _ 18, 13 3/8' 9 5/8" • • II Granite Point Platform Moncla BOP Iiiknrl■Alaska.1.i.(. r E v ltrPaCrillinal f illi l 4.54' 0 Hydril, ti GK 13 5/8-5000 . raw- I11 ill IiI 111111 III III III III III CIW-U Variable rams H ' 11 .. lii:ia li 2 7/8-5 4.67' _ i� G. I „ 13 5/8-5000 rail'. Blind Barns iii iii:iii iii iii ' 1111111, - ---_- -- - Choke and Kill valves 1. 21/16 5M _ ai 111 III Ill-ISI III �� 0. — lett : Mud Cross ■ a ■ "._ 226 � i illik■ _ i� 41/165M EFO z III•'14 1 t(tUq�7J CUi lulu it Ji [PJ Riser 135/85M FE X 13 5/8 SM FE EIS iiii ill ill iii III III III III III III Spacer spoolai 135/85M FEX11SM Iil til lit tit iit • O U Q u 000 0000 O U O U O U Q U u 0 U u 0 0 a s-INCOTLO , n1 CO TS Srl l0 I, CO 01 2 2 2 2 2 al 2 2 2 2 2 2 2 2 2 u u u u u u u u u u 0 .-a r a m y in al .i CV m a In t.o n CO m , v -o -0 a o a s a a U a '0 -0 'O-0 Hifi 0 0 0 � � o 0 .0 G 0 0 0 0C G w 0o w_ L 55555555558 ,2 ; O d 6 t1 , e. _ c > Y al al a) al Y d o o- Y al Cl a) al a) ,_ ] .4. > E E E E E - YJ U O o o o o o o o o o C > = U U U U U U U Q U Q U rn asv a w Y !'= 0 C L 0, 5 M u 2 to HH HH N Q) r . 03... LO , 03 0, r.._■I --7 a J ce w a LU W 0 Mro . f . z O II tY> ce _ J rJ Q cE O 00 LL CI. 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CD C Z Z oOOCDH �r01ZQ * Q Q -N O 0 W U U CL CC J J U) _ OZ p 0 2DII0 > r H JOZ �,w a LLZ � c = 0, Z n z < C H J 0 D 0 IF u_ 0 I Moncla Rig 404 BOP Test Procedure H;,cor!,Alaska LIS: Attachment#1 Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Moncla Rig 404, WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing(EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off.Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful,shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV.As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve, or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand, or MU landing(test)joint to lift-threads d) For ESP wells-Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations Engineer(Hilcorp), Mr.Guy Schwartz(AOGCC)and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path,test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure(floor valves,gas detection, etc.) • • Moncla Rig 404 BOP Test Procedure �.�.c Attachment#1 Hilcorp Alaska, f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug)in tubing head. Test BOPE per standard procedure. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Remove wear bushing. a) Use inverted test plug to pull wear busing. MU to joint of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same-RIH with test plug on joint of tubing. Install a pump-in sub w/test line plus an open TIW or lower Kelly valve in top of test joint w/open IBOP. 3) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack and all lines with rig pump-install chart recorder on test line connected to pump-in sub below safety valve and IBOP in test joint assembly. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder(test pressures will be indicated in Sundry). 3) Referencing the attached schematics test rams and valves as follows. a) Close 1st valve on standpipe manifold, close valves 1, 2, 10 on choke manifold and close the annular preventer, open safety valve on top of test jt and close IBOP. Pressure test to 250 psi for 5 minutes and 2,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank and open annular. b) Close pipe rams and open annular preventer, close safety valve and open IBOP on test joint, close outside valve on kill side of mud cross,open 1st valve of standpipe, close valves 3,4&9 on choke manifold, open valves 1&2 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack,test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. d) Close inside valve/open outside valve on kill side of mud cross, close valves 5&6/open valves 3&4 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. e) Close manual and super choke/open valves 5&6 on choke manifold. Pressure up to^'1200 psi and bleed off 200—300#s recording change and stabilization. If passes after 5 minutes, bleed of pressure back to tank. f) Close HCR(outside valve on choke side of mud cross), open manual&super choke. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. 11 • • Moncla Rig 404 BOP Test Procedure Hileorp Alaskan LLCAttachment#1 g) Close inside valve/open outside valve(HCR) on choke side of mud cross. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. h) Ensure all pressure is bled off-open pipe rams and pull test joint leaving test plug/2-way check in place. Close blind rams and attach test line to valve 10 on choke manifold,close valve 7&8/open valve 10 on choke manifold. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. i) Test additional floor valves(TIW or Lower Kelly Valve)and IBOPs as necessary. STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be+/-3,000 psi. 3) Close Annular Preventer,the Pipe Rams,and HCR. Close 2nd set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre- charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. 8) Once 200 psi pressure build is reached,turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure(+/-3,000 psi). Note: Make sure the electric pump is turned to"Auto", not"Manual"so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves,for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424)in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. • • Granite Point Platform 2017 BOP Stack(Kuukpik) /15 04/24/2017 Hilrnrp Alxako,HA: Rig Floor Itt 16" Pipe O O fffl rrti fFfil f n (ffil rrti 3.74' Shaffer III Iil liliii its is Shaffer S" • 2 7/8-5.5 Variables 2.83' :*_ _ - 13 5/8 5M -., Blind 00 Imo.O 2 1/16 5M manual and HCR valve 2 1/16 5M manual and HCR valve T In IntiurIn 1.0,1.76 1f: III iil i�iiin. i 1, e r L 135 85M 144 •=••'. 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Rolling BOP Test Procedure: Kuukpik 5 — Oil/Gas Producers, Water/Gas Injectors Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile &lift threads were deemed good, but still unable to get good tests 1) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations Engineer(Hilcorp), Guy Schwartz (AOGCC-guy.schwartz@alaska.gov),Jim Regg (AOGCC-jim.regg@alaska.gov) and Michael Quick (AOGCC—Michael.quick@alaska.gov)via email explaining the wellhead situation prior to performing the rolling test. If on Federal land contact BLM representative Amanda Eagle (aeagle@blm.com) and Mutasim Elganzoory(melganzoory@blm.com). AOGCC and BLM may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: 2) With stack out of the test path, test choke manifold per standard procedure 3) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) Kill and choke line valve will also be tested during this time. 4) During these tests the test chart needs to be set to 60 min instead of 12 hours so chart shows a better graph. Need to station hands in cellar going over all connections on the BOPS looking for the slightest leak. Also need a man looking down the hole to confirm that the BOPs are not leaking. Test#1=Annular, HCR Choke, and HCR Kill. Test#2=Upper Pipe Rams, HCR Choke, and HCR Kill. Test#3=Upper Pipe Rams, Manual Choke, and Manual Kill. Test#4=Lower Pipe Rams. 5) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. 6) Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) 7) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 8) Pull hanger to surface. (Making tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid and sweep off any oil cap that may be present. 9) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE as per Kuukpik's standard test procedure. Or POOH laying down all the tubing and use the normal test plug to finish the tests that were not completed as per regulatory approval. • ! Kuukpik 5 BOP Test Procedure FIi1 orp Alaska.LI . Attachment#1 If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree and test. May have to tap out if scaled up or paraffined up if well is not dead may have to be done w/ pressure lubricator (diesel or acid could help) 2) If unsuccessful, or BPV profile is eroded and well is dead. Best practice is to have two barriers a. Fluid column b. Set wire line plug or tag fluid level with slick line to establish static fluid level or shoot fluid level with an echo meter gun. 3) Shoot off tubing very shallow ( 300-500' most likely just under SSSV if applicable) 4) Spear hanger w/ upside down cup provided by fishing company 5) Proceed to get best test we can achieve against cup and confirm no visual leaks on all flanges of BOPE 6) Notify Hilcorp Anchorage Operations Engineer and AOGCC of situation 7) Pull hanger and cut off stub 8) P/U test plug and set same. 9) Perform complete BOPE test as per Kuukpik's standard procedure • • � R / k � 2 2 a 2 c 2E 022 \ / 2k ° § / « � E ® E 01 o 2 7 , § 2 k�- - f ƒ CL« / / m % ' \ % I a)0 \.§ In C 0- 9' o ase 2 % a) a) 2 2 \ � � � k k $ % a)>- I- co Zre a / a) W et Qa • % � ƒ CD Cl) 2 2 O a it eL / 43 4 ' \/ a)�as = o _ � k � 0 0 CCI 0 \ a ka 0 •a) ) L. e .E % a = 2 0 k o ƒ13 a a 0 k SR E ■ a)»$ § a) § / / .5) 2 2p Co w t $ � 0 c 2 § ct a § 0 o. E % co a cts « m ' 0 ■ 4Ct 2 % f E 0 X ¥ 2 e CO q q Q co x CD I cm >< ( .D) 0 .< § * / e $ 2 s.° � w / � co .. 0 f a k U Z g > z 2 /C 0 \ E 0 2 $ k 9 2 ! • Schwartz, Guy L (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Friday, May 05, 2017 9:54 AM To: Schwartz,Guy L(DOA); Dan Marlowe Subject: RE: PLug for Sidetrack- GPS 11-24(PTD 167-057) There is always the concern of getting an adequate FIT, however we haven't had issues with it yet on a few of the past wells that were questionable whether there was cement behind pipe or not. If we are unable to get a good FIT we will make sure to get approval and perform a squeeze on the window at that time. Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From:Schwartz,Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Friday, May 05,2017 9:39 AM To: Monty Myers<mmyers@hilcorp.com>; Dan Marlowe<dmarlowe@hilcorp.com> Subject: RE: PLug for Sidetrack-GPS 11-24(PTD 167-057) Monty, Any concerns with getting an adequate FIT once window is cut? Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Monty Myers [mailto:mmyers@hilcorp.com] Sent: Friday, May 05,2017 9:24 AM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov>; Dan Marlowe<dmarlowe@hilcorp.com> Subject: RE: PLug for Sidetrack-GPS 11-24(PTD 167-057) We would typically mill a window and come off to the right of highside to let the mills walk to the right. We do this when there is no cement behind pipe so that we don't track down the casing annulus. After we run the liner, we will have to pump enough cement to bring it into the window and above the liner top. A 2- stage job could be required. Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 1 • • Cell: 907.538.1168 From:Schwartz,Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent:Thursday, May 04, 2017 2:29 PM To: Dan Marlowe<dmarlowe@hilcorp.com> Cc:Monty Myers<mmyers@hilcorp.com> Subject: PLug for Sidetrack-GPS 11-24(PTD 167-057) Dan, Don't see any analysis or discussion of the cement quality behind the 9 5/8" casing at the window exit. The schematic shows a TOC at 9100 ft. Well below the window How is drilling going to address this? Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guv.schwartz@alaska.gov). 2 • • Schwartz, Guy L (DOA) From: Dan Marlowe <dmarlowe@hilcorp.com> Sent: Friday, May 05, 2017 8:39 AM To: Schwartz, Guy L(DOA) Cc: Monty Myers Subject: RE: PLug for Sidetrack-GPS 11-24(PTD 167-057) I will let Monty address Cement behind the 9-5/8" at the window. We do intend to get caliper logs and a pressure test during the decomplete For the 13-3/8" here are the notes from 1968.The casing parted during install so they ran a die collar then spent several days squeezing it multiple times do to the DV collar not closing. OPERATOR Mobil Oil Corporation FIELD Granite Point WELL NO. Granite Point State 11-24 Sec. 13 T ION R 12W Signed C. C. Woodruff DATE March ", 1968 Title Area Engineer Date 10/12-10/17 Opening To 16" 635'/4035'; Running & Cementing 13 3/8" Casing @ 4030 Ran in with a 16" hole opener and opened hole to 635'/4035' . Conditioned hole to run casing. Ran 97 jts. of 13 3/8" casing. Pipe parted while installing landing hub, and landing joints. Pulled and ran die collar on 11 joints of casing. Landed casing at 4030' and cemented in two stages. First stage pumped 640 sax of Class "G" cement with 3/4% TIC. Opened DV collar and pumped 1260 sax of Class "G" cement. DV tool did not close. 10/17-10/19 D.O.C. ; Pressure Testing_ Casinj & D.V. Co11ar, Squeezing D.V. Collar Tagged hard cement at 2271'. Drilled out D.V. tool at 2306'. Pressure to I with 2000 psi, bled off to 1200 psi. Ran in with 13 3/8" Baker retainer prematurely at 1256'. Drilled out retainer and pushed to bottom. Ran a Halliburton RTTS packer and set at 2245' . Mixed 100 sax Class "G" cement 37, CaC12. Squeezed 60 sax in 10 to 15 min. stages for 2 hours. Squeezed 1 sax in stages for 3 hours at a final presssure of 900 psi. Moved retainer i2185'. Squeezed 115 sax in stages with a final pressure of 2000 psi. He: pressure for one hour. 10/19-10/211 C.O.C. ; Pressure Test D.V. Col1a5Changed Mud System To Fresh Water;' Rect Iron. Tagged cement top at 2259'. D.O.C. to 2305' and tested D.V. collar with s Pressure bled back to 1200 psi. and held C.O. to 4030' and changed to fre 1 • • From:Schwartz,Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent:Thursday, May 04,2017 2:36 PM To: Dan Marlowe<dmarlowe@hilcorp.com> Cc: Monty Myers<mmyers@hilcorp.com> Subject: RE: PLug for Sidetrack-GPS 11-24(PTD 167-057) Also, can you discuss what issues are relevant to the 13 3/8"surface casing. (bad area at 440' md./is it fully cemented etc.) Are there any issues with it and can it be repaired while you have rig on site. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From:Schwartz,Guy L(DOA) Sent:Thursday, May 04,2017 2:29 PM To: Dan Marlowe(dmarlowe@hilcorp.com)<dmarlowe@hilcorp.com> Cc:mmyers@hilcorp.com Subject: PLug for Sidetrack-GPS 11-24(PTD 167-057) Dan, Don't see any analysis or discussion of the cement quality behind the 9 5/8"casing at the window exit. The schematic shows a TOC at 9100 ft. Well below the window How is drilling going to address this? Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). 2 e Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill"box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon"or j "Suspend"boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon"box is checked in Box 15 (Well Status after proposed Geologist work) the initial reviewer will cross out that erroneous entry and initial J then it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended" box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, they will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the"Intent: Plug for Redrill"comment or code, they will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time,they will also review the list of suspended wells for accuracy. • STATE OF ALASKA S E P 2 8 2 015 A KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing El Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill LI Perforate New Pool❑ Repair Well LI Re-enter Susp Well❑ Other: Suspended Well Inspection 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 2 Exploratory❑ 167-057 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service El 6.API Number: Anchorage,AK 99503 50-733-20046-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018761 Granite Pt St 11-24 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Granite Point Field/Middle Kenai Oil Pool 11.Present Well Condition Summary: Total Depth measured 11,800 feet Plugs measured 9,440(cement) feet true vertical 11,071 feet Junk measured N/A feet Effective Depth measured 9,440 feet Packer measured feet true vertical 8,780 feet true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor 635' 18" 635' 633' Surface 4,030' 13-3/8" 4,030' 3,796' 3,090 psi 1,540 psi Intermediate Production 10,086' 9-5/8" 10,086' 9,418' 5,750 psi 3,090 psi Liner 1,835' 7" 11,798' 11,069' 11,220 psi 8,510 psi Perforation depth Measured depth N/A feet � r True Vertical depth N/A feet Ci I` 4 J µ Tubing(size,grade,measured and true vertical depth) N/A N/A N/A N/A Packers and SSSV(type,measured and true vertical depth) N/A&N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑ Exploratory❑ Development 2 Service ❑ Stratigraphic El Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR El WINJ ❑ WAG ❑ GINJ❑ 3USP❑] SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 310-358 Contact Dan Marlowe Email dmarlowe@hilcorp.com Printed Name Dan Marlowe Title Operations Engineer l ! Signature _.....e.,, ,/. , Phone (907)283-1329 Date 4 �Q j5 Form 10-404 Revised 5/2015 1047-'1{ RBDMS3(. SEP 9 1015 Submit Original Only • Suspended Well Inspection Data Well: GPP 11-24 Surface Location: 2383' FNL, 1368' FWL, Sec 13,T10N, R12W S.M. Permit to Drill: 167-057 API: 50-733-20046-00 AOGCC Inspection Date: 9/25/15 AOGCC Inspector: Matt Herrera Size Pressure(psi) Tubing N/A Casing IA 0/260 OA 0/260 *Note: Wellhead pressures to be recorded monthly at minimum. Other Notes: • Condition of Wellhead: Good • Condition of Surrounding Surface Location: Good • Follow Up Actions needed: None/ Readings psi Attachments: • Current Well Schematic • Picture(s) • Plat- 1/4mile radius of wellbore • Correspondence/Suspended Well Inspection Report • • • Granite Point Platform Well# 11-24 Temporarily Suspended: 9/30/97 Hileorn Alaska,LLC RKB=114.75"; 43' Rig Floor to Wellhead FMC Unihead CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 13-3/8 61 K-55 BTC Surf 4,030 9-5/8 40-47 N-80/S-95 BTC Surf 10,086 7" 29 P-110 X-line 9,963 11,798 Tubin2 Fish 3-1/2" 9.2 L-80 SC-BTC 9,440 10,010 COMPLETION DETAIL NO. ITEM DEPTH 1 Top Cement Plug(11 BBLS) 9,440'-9,585' 2 HES EZ-SV Cement Retainter 9,585' 3 Bottom Cement Plug(47 BBLS ) 9,587'-11,165' 4 Otis"XO" Sliding Sleeve w/valve 9,836' 5 Fish: Wash-pipe Shoe(L=4.35', OD= 8-1/2", ???? ID= 7-1/8") A, 2 6 Otis"XO" Sliding Sleeve w/valve 10,480' 7 Otis"Q"Profile Nipple(ID=2.635") 10,699' a TOF @ 9,824' : m •::::::::3 Note: Top of tubing fish is @ 9,835'. • 4 ••:Flit, 5 Cement top is calculated. TOL @ 9,963' : Hole and bad spots in casing from 9,722' to 9,838'. \' See morning reports for more detail. ABANDONED PERFORATION DATA Accum. Date • Zone Top Btm Amt SPF Last Opr. Present Condition . 9,765' 9,766' 1' 8 1/6/68 Block cmt sqz 28 cuft of class"G". tested to 5,000 psi. . C2 9,836' 9,866' 30' 4 1/10/68 Perf f/Production 9,950' 9,951' 1' 4 1/3/68 Pressure tested to 5,000 psi,no break down xo .•.•1 6 C5 10,095' 10,130' 35' 4 _ 1/10/68 Perf f/Production C5 10,150' 10,240' 90' 4 1/10/68 Perf f/Production C6 10,315' 10,350' 35' 4 1/10/68 Perff/Production ►ag :.:.2 7 10,400' 10,401' 1' 4 1/3/68 Pressure tested to 5,000 psi,no •-t break down :•10; C7 10,535' 10,560' 25' 8 10/25/68 Perf f/Production C7 10,580' 10,660' 80' 8 10/25/68 Perf f/Production C7 10,675' 10,700' 25' 8 10/25/68 Perf f/Production q 10,750' 10,751' 1' 4 1/2/68 Pressure tested to 5,000 psi,no PDTD=9,440' break down C9 11,135' 11,165' 30' 4 12/30/67 Isolated below retainer @ 11,108' MAX HOLE ANGLE±25 0 O:\Alaska\Fields\Granite Point\Granite Point\Wells\GP 11-24\Schematics\GP 11-24 Schematic 9-30-97.doc REVISED: 10/23/97 DRAWN BY: MWD 4 V 11"''' '' (1111':: -— — k4e, • '', , -.. , . ., ...., -.„ .,.. 1 ','2,* 11 a ...* ... r I ...,,, , -- - . 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LI .. .., 0 tti 1' $ • • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 09/25/15 Inspector: Matt Herrera Operator: HILCORP Well Name: Granite Pt State 11-24 - Oper.Rep: James Madrid _ PTD No.: 1670570 Oper.Phone: 907-776-6650 Location Verified? Yes Oper.Email: jmadrid@hilcorp.com If Verified,How? LAT/LONG Onshore/Offshore: Offshore Suspension Date: 09/30/97 Date AOGCC Notified: 09/23/15 Sundry No.: 397-158 Type of Inspection: Subsequent Wellbore Diagram Avail.? Yes • Well Pressures(psi): Tubing 0 Photos Taken? Yes - IA 260 OA 260 Condition of Wellhead: Good,Gauges operable Condition of Surrounding Surface Location: Good no standing water or oil sheen discoloration around well head or in cellar area Follow Up Actions Needed: Monitor IA and OA pressure and visually inspection by Operator Comments No SSV Attachments: Photo(1) REVIEWED BY: Insp.Supry .61Z— IZIZOic Comm SCANNED SEP 0 72016 PLB 12/2014 2015-0925_Suspend_GranitePt_State_11-24_mh.xlsx • • 1• i ' ., «w _ i yi p . �. t 4* ''',..°;:�f $irt ,r ,i.L..) '":-.i--.- x . :„4,,, ... . .., ,if, . i , .., . , ,7:: . t;., ,t ell ,rCD 1 '. ... ' ) 1', ' ' ' ; el , at cLi yam, t #.,.,ii4 a)I it. - :: 44 ct u cu H 1—ik'; , pry. t , Fs. oUos. 0 • \ a c4 c) Ir C . Lesiii# r4aA, L.., b�q o 4 0 C7 UNSCANNED, OVERSIZED MATERIALS AVAILABLE: To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission ,333 W. 7th Ave., Ste. 100, Anchorage, Alaska 99501 Voice (907) 279-1433 1Fax (907) 276-7542 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 09/25/10 Inspector: Lou Grimaldi Operator: Union Oil Company Well Name: Granite Pt State 11 -24 Oper. Rep: Jerry Collins PTD No.: 167 -057 Oper. Phone: 776 -6650 Location Verified? Yes Oper. Email: If Verified, How? Other (specify in comments) Onshore / Offshore: Offshore Suspension Date: 09/30/97 Date AOGCC Notified: unkown Sundry No.: 397 -158 Type of Inspection: Initial Wellbore Diagram Avail.? No Well Pressures (psi): Tubing 450 Photos Taken? Yes IA 440 OA 500/18 i ' %4 Condition of " — t ,�k�° Wellhead: Clean and secure Condition of Surrounding Surface Granite Pt Platform; Wellroom clean and secure ' Location: Follow Up Actions None Needed: Attachments: Photos (3) REVIEWED BY: Insp. Supry Cgi q iif it cr... Comm PLB 09/2010 2010- 0925_ Suspend _Granite_Pt_State_11- 24_Ig.xls Suspended Well Inspection — Granite Pt Field 11 -24 (Granite Pt Platform) PTD 1670570 Photos by AOGCC Inspector L. Grimaldi 9/25/2010 I, I . - , a a its► , I, i,i i- e l ��., t ,.. 41. � x � 4,,... { • L ASK A SEAN PARNELL, GOVERNOR ALAS 1�TD KA OIL A GAS 333 W. 7th AVENUE, SUITE 100 CO COMUSSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Timothy C. Brandenburg '/ Drilling Manager � I _' ' / Union Oil Company of California } PO Box 196247 r Anchorage, AK 99519 Re: Granite Point Field, Middle Kenai Oil Pool, Granite PT ST 11 -24 Sund ry Number: 310 -358 Dear Mr. Brandenburg: 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. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration 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. e 1 r' n or ma /�i C issioner DATED this / 1 day of November, 2010. Encl. Z010 STATE OF ALASKA OCT 2 8 2010 ALASKA OIL AND GAS CONSERVATION COMMISSION &sSe�i3��iio�t APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Request for Suspended Well Renewal 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development n Exploratory ❑ 167 -057 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: PO Box 196247, Anchorage, AK 99519 50- 733 - 20046 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No P1 Granite PT ST 11 -24 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL0018761 [Granite Point Platform] Granite PT Field / Middle Kenai Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11,800 11,071 9,440 8,780i 9,440 (cement) N/A Casing Length Size MD / TVD Burst Collapse Structural Conductor 635' 18" 635' 633' Surface 4,030' 13 -3/8" 4,030' 3,796' 3,090 psi 1,540 psi Intermediate Production 10,086' 9 -5/8" 10,086' 9,418' 5,750 psi 3,090 psi Liner 1,835' 7" 11,798' 11,069' 11,220 psi 8,510 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A / N/A N/A / N/A 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development Service ❑ 14. Estimated Date for N/A 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended 16. Verbal Approval: Date: N/A WINJ F] GINJ F1 WAG El Abandoned F-1 Commission Representative: GSTOR El SPLUG E] 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer 263 -7831 Printed Name AP Timothy C. Brandenburg Title Drilling Manager y( Signature Phone 276 -7600 Date ( � 2 5 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: �l Subsequent Form Required: / ` o APPROVED BY j Apprf 4 M MS COMMISSIONER THE COMMISSION Date: Form 10-403 RevisF112 R Submit in Duplicate / • Suspended Well Data Well: GP 11 -24 Surface Location: 2383' FNL, 1368' FWL, Sec 13, T10N, R12W S.M. Permit to Drill: 167 -057 API: 50- 733 - 20046 -00 AOGCC Inspection Date: 9/25/10 AOGCC Inspector: Lou Grimaldi Size Pressure (psi) Tubing N/A N/A Casing 9 -5/8" 440 13 -3/8" 450 18" 17 *Note: Wellhead pressures to be recorded daily. Other Notes: • Inspector's comments: Wellhead clean & secure. Well room clean. • Well was suspended on September 30, 1997. • As shown on the accompanying TIO plot, there is pressure on the 9 5/8" and 13 3/8" casing. Pressures have remained fairly stable for the last 2 years. • Wellhead pressures will continue to be monitored on a daily basis. • It is proposed that well GP 11 -24 be maintained in suspended status until the Granite Point Platform production is shut -in and platform abandonment commences. Attachments: • Current Well Schematic • 3 Year TIO Plot GRANITE POINT PLATFORM ALASKA DRILLING WELL # 11 -24 U N O CAL 76 Temporarily Suspended: 9/30/97 RKB = 114.75 "; 43' Rig Floor to Wellhead FMC Unihead CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 13 -3/8 61 K -55 BTC Surf 4,030 9 -5/8 40 -47 N- 80/S -95 BTC Surf 10,086 7 29 P -110 X -line 9,963 11,798 Tubine Fish 3 -1/2" 9.2 L -80 SC -BTC 9,440 10,010 COMPLETION DETAIL NO. ITEM DEPTH 1 Top Cement Plug (11 BBLS) 9,440'- 9,585' 2 HES EZ -SV Cement Retainter 9,585' 3 Bottom Cement Plug (47 BBLS) 9,587' - 11,165' 4 Otis "XO" Sliding Sleeve w/ valve 9,836' 5 Fish: Wash -pipe Shoe (L= 4.35', OD = 8 -1/2 ", ? ? ?? 1 ID = 7 -1/8 ") 2 6 Otis "XO" Sliding Sleeve w/ valve 10,480' 7 Otis "Q" Profile Nipple (11) = 2.635 ") 10,699' TOF @ 9,824' 5 Note: Top of tubing fish is @ 9,835 TOL @ 9,963' Cement top is calculated. Hole and bad spots in casing from 9,722' to 9,838'. See morning reports for more detail. ABANDONED PERFORATION DATA Accum. Date Zone Top Btm Amt SPF Last Opr. Present Condition 9,765' 9,766' 1' 8 1/6/68 Block cmt sqz 28 cult of class "G ". tested to 5,000 psi. C2 9,836' 9,866' 30' 4 1/10/68 Perf f/ Production X0 6 9,950' 9,951' 1' 4 1/3/68 Pressure tested to 5,000 psi, no break down J C5 10,095' 10,130' 35' 4 1/10/68 Perff/ Production 7 C5 10,150' 10,240' 1 90' 4 1/10/68 Perf f/ Production C6 10,315' 10,350' 35' 4 1/10/68 Perf f/ Production 10,400' 10,401' 1' 4 1/3/68 Pressure tested to 5,000 psi, no break down C7 10,535' 10,560' 25' 8 10/25/68 Perf f/ Production C7 10,580' 10 80' 8 10/25/68 Perf f/ Production PDTD = 9,440' C7 10,675' 10,700' 25' 8 10/25/68 Perf f/ Production 10,750' 10,751' 1' 4 1/2/68 Pressure tested to 5,000 psi, no MAX HOLE ANGLE ± 25 ° break down C9 11,135' 11,165' 30' 4 12/30/67 Isolated below retainer@ 11,108' O:\ NAU \MCBU\Alaska\Depts \CI_Oil_Ops \Well Fi 10/23/97 DRAWN BY: MWD i Plot Pressure & Rate vs Time - Well GP 11 -24 600 �9 5/8" 13 3/8" 500 20" ( t" vu uuwv IV ru 400 1� • I l� 1 L 3 300 a� a 200 100 0 h ao ao ao ao tT rn rn rn o o O O 0 0 0 0 0 0 0 0 0 CD CS STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Li Repair Well Lj Plug Perforations Stimulate Lj Other ✓ I Suspended Well Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Inspection Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re-enter Suspended Well ❑ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Q Exploratory ❑ Stratigraphic❑ Service ❑ 167-057 3. Address: PO Box 196247, Anchorage, AK 99519 6.,API Number: 50-733-20046-0000 7. Prope* Designation (Lease Number): 8. Well Name�and Number: ADL0018761 [Granite Point Platform] Granite PT ST 11-24 9. Field/Pool(s): \1 Granite PT Field / Middle Kenai Oil Pool 10. Present Well Condition Summary: Total Depth measured 11,800 feet Plugs (measured) 9,440 (cement) feet true vertical 11,071 feet Junk (measured) N/A feet Effective Depth measured 9,440 feet Packer (measured) N/A feet true vertical 8,780 feet (true vertical) N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 635' 18" 635' 633' Surface 4,030' 13-3/8" 4,030' 3,796' 3,090 psi 1,540 psi Intermediate Production 10,086' 9-5/8" 10,086' 9,418' 5,750 psi 3,090 psi Liner 1,835' 7" 11,798' 11,069' 11,220 psi 8,510 psi Perforation depth: Measured depth: N/A True Vertical depth: N/A Tubing (size, grade, measured and true vertical depth): N/A N/A N/A N/A Packers and SSSV (type, measured and true vertical depth): N/A N/A N/A N/A P 11. Stimulation or cement squeeze summary: Intervals treated (measured):0 Zola N/A Treatment descriptions including volumes used and final pressure: UK�+� N/A daphatalln 12. Representative Daily Average Production or a Oil -Bbl Gas-Mcf I Water -Bbl I Casing Pressure Tubing Pressure Prior to well operation: 0 0 10 1440 psi N/A Subsequent to operation: 0 0 10 1440 psi N/A 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory[] Develo ment❑✓ Service ❑ Daily Report of Well Operations N/A 15. Well Status after work: Oil Ll Gas Lj WDSPL Well Remains in'SUSP' Status ==> GSTOR ❑ WAG ❑ GINJ ❑ WINJ ❑ SPLUG ❑ 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Chris Kanyer 263-7831 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature Phone 276-7600 Date 10/11/10 1-211 -IMS OCT 21201 Form 10-404 Revised 7/2009 Submit Original Only r� u Suspended Well Inspection Data Well: GP 11-24 Surface Location: 2383' FNL, 1368' FWL, Sec 13, T10N, R12W S.M. Permit to Drill: 167-057 API: 50-733-20046-00 AOGCC Inspection Date: 9/25/10 AOGCC Inspector: Lou Griamldi *Note: Wellhead pressures to be recorded monthly at minimum. Other Notes: • Wellhead clean & secure. Wellroom clean. Attachments: • Current Well Schematic • Picture(s) • Plat - 1/4mile radius of wellbore • Correspondence/Suspended Well Inspection Report Size Pressure (psi) Tubing N/A N/A Casing 9-5/8" 440 13-3/8" 450 18" 17 *Note: Wellhead pressures to be recorded monthly at minimum. Other Notes: • Wellhead clean & secure. Wellroom clean. Attachments: • Current Well Schematic • Picture(s) • Plat - 1/4mile radius of wellbore • Correspondence/Suspended Well Inspection Report ALASKA DRILLING GRANITE POINT PLATFORM WELL # 11-24 UNOCAL""" Temporarily Suspended: 9/30/97 RKB = 114.75"; 43' Rig Floor to Wellhead FMC Unihead CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 13-3/8 61 K-55 BTC Surf 4,030 9-5/8 40-47 N -80/S-95 BTC Surf 10,086 7" 29 P-110 X -line 9,963 11,798 Tubing Fish 3-1/2" 9.2 L-80 SC -BTC 9,440 10,010 COMPLETION DETAIL NO. ITEM DEPTH 1 Top Cement Plug (11 BBLS) 9,440'-9,585' 2 HES EZ -SV Cement Retainter 9,585' 3 Bottom Cement Plug (47 BBLS) 9,587'-11,165' 4 Otis "XO" Sliding Sleeve w/ valve 9,836' 5 Fish: Wash -pipe Shoe (L=4.35', OD = 8-1/2", ???? 1 ID = 7-1/8") 2 6 Otis "XO" Sliding Sleeve w/ valve 10,480' 7 Otis "Q" Profile Nipple (ID = 2.635") 10,699' TOF @ 9,824' 5 Note: Top of tubing fish is @ 9,835'. TOL @ 9,963' Cement top is calculated. Hole and bad spots in casing from 9,722' to 9,838'. See morning reports for more detail. 6 7 PDTD = 9,440' MAX HOLE ANGLE ± 25 ° ARANnnNFD PFRFnRATION DATA Zone Top Btm Amt Accum. SPF Date Last Opr. Present Condition 9,765' 9,766' 1' 8 1/6/68 Block curt sqz 28 cuft of class "G". tested to 5,000 psi. C2 1 9,836' 9,866' 30' 4 1/10/68 Perf f/ Production 9,950' 9,951' 1' 4 1/3/68 Pressure tested to 5,000 psi, no break down C5 10,095' 10,130' 35' 4 1/10/68 Perf f/ Production C5 10,150' 10,240' 90' 4 1/10/68 Perf f/Production C6 10,315' 10,350' 35' 4 1/10/68 Perff/ Production 10,400' 10,401' 1' 4 1/3/68 Pressure tested to 5,000 psi, no break down C7 10,535' 10,560' 25' 8 10/25/68 Perf f/ Production C7 10,580' 10,660' 80' 8 10/25/68 Perf f/Production C7 10,675' 10,700' 25' 8 10/25/68 Perff/ Production 10,750' 10,751' 1' 4 1/2/68 Pressure tested to 5,000 psi, no break down C9 11,135' 11,165' 30' 4 12/30/67 Isolated below retainer@ 11,108' O:\NAU\MCBU\Alaska\Depts\CI_Oil_Ops\Well Files\Suspended Wells\GPP 11-24 Schematic 9-30-97.doc REVISED: 10/23/97 DRAWN BY: MWD 0 0 GRANITE POINT PLATFORM WELLSLOT DIAGRAM Leg #2 North Corner 01/01/10 MCI MUCI-2 22-13RD2 S3I S/I S I32-13RD GP -51 S/I rr 5 31-13 10 GP -50 S/I �i 6' 24-13RD 11-13RD 9 TP&A 7 8� 42 -23RD Leg 2#3 East Corner (9 0 0 0 Producer Dual Gas Well Injector Completion 12-24 54 55 S/I su e 3 4 2 S%] 012 r io 6 Q suspeno 9 8 33-14RD Leg #1 Leg #4 West Corner South Corner 53- 52 a pz, , . y also T r <.� A V4 f STATE OF ALASKA ALASKA OIL AND GAS CONSEftm-noN .COMMISSION Strspended Well Inspectim Report, date Vnspected: � 5�;� y` lnspectbr: � operator. e; Well Nam Oyer: Rep: � l .Q � /�✓� :i J c..�`i • r PTD No.: _ Op., Phone: t;ocabon Verified? 7S Oper. Email: If Vented, Km?— On"* / Gffsiwte: �i3 I y Suspension Ogle:T .: {�'~ Ostia AOGCE NO %& Sung+ No.: TJrtis of tri9oebtion: � U/ Welt Piessu►es C�.r� YVeI� 4iaprem Avali.? (ow): Tubby Ptatcs TWwn? t F� IA 9A '1 - or P aDWa0w Svspwxibd Weft +ctspecttjn Formals March 31, 2009 Dale Haines Alaska Area Operations Manager Cathy Foerster Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Re: Suspended Wells Dear Commissioner Foerster, \(-*-`1- c-:) S'Z Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7951 Fax 907 263 7607 Email Daleah@chevron.com Please find the attached corrections to the suspended and long term shut in well list as provided in your letter dated January 28, 2009. As per our discussion the submitted list needs to be expanded to include additional wells that may not currently be identified on the list provided by the Commission. We also provide the Commission with an annual shut in well report that is sent to Steve McMains. This report was mailed to the Commission on March 30, 2009. At this time I cannot validate that we have provided the Commission with a comprehensive list of all suspended wells so it is our intention to validate the two lists and to review our records to ensure that we have accurately responded to the request. We will therefore endeavor to provide a comprehensive list to the Commission in the next two weeks. Chris Myers will contact Jim Regg to discuss the scheduling inspections of the suspended wells in 2009. If you have any questions about this submittal, please contact myself. Sincerely, r1 N Dale Haines Alaska Area Operations Manager Attachment Cc: Tim Brandenburg Chris Myers Dave Cole Union Oil Company of California / A Chevron Company http://www.chevron.com Corrections for the referenced list of suspended and long-term shut-in wells operated by UNOCAL. Well Name API# PTD Current Listed Status Corrected Status Bruce 18742 #40 50-733-20339-00 181-022 Suspended Shut -In SRU 14-15 50-133-10145-01 100-146 Suspended Shut -In SCU 243B-04 50-133-20489-00 199-055 Suspended Shut -In ._ � 6 • � -- I-� � ; iii r A11ASKA OIL AND GAS CONSERVATION CUMMSSION i January 28, 2009 CERTIFIED MAIL RETURN RECEIPT REQUESTED 7005 1820 0001 2499 6019 Dale l laines UNOCAL :800 Centerpoint Dr. Ste 100 Anchorage AK 99503 Re: Notice of Revised Suspended Wells Regulations and Request for Verification of Suspended and Shut-in Well Information Dear Ivlr. Haines: SARAH PAUN, GOVERNOR 333 W. 7th AVENUE. SUITE 100 AW,HORAGE.ALASKA 9950'-3539 PHONE (907) 279-'433 FAY. (907)276-79:2 Enclosed are the Alaska Oil and Gas Conservation Commission's revised regulations regarding suspended wells (i.e., 20 AAC 25.110). Also enclosed is a list of' suspended and long-term shut-in wells operated by UNOCAL. For each list, please verify the information for each well and provide any corrections by April 1, 2009. location inspections required under 20 AAC 25.110 should be coordinated with Jim Regg at 907-793-1236 or' im.rcgg@alaska.gov. fl'vou 11_ut,_ '_joy gtiestionsrngard;n� this notice. -!case contact Tom \4_wndf,1 :It 907-79) `- 1250 or tom.maundcr@alaska.gov. Sincerely, Cathy P. Foerster Com.m.issioner l;nclosures Opermor UNION OIL CO OF CALIFORNIA Field fermi( API Number Well Name Suspended and Slltat In Wells BIRCH HILL 8/11/1997 2428 FNL 165-001-0 50-133-10029-00-00 BIRCH HILL UNIT 22-25 DEEP CREEK ADL0018761 207-123-0 50-231-20031-00-00 HAPPY VALLEY 8-12 GRANITE PT Sec 13 1411 4-s 196-045-0 50-733-20472-00-00 GRANITE POINT 52 196-013-0 50-733-20470-00-00 GRANITE POINT 54 197.145-0 50-733-20479-00-00 GRANITE POINT 55 167-057-0 50-733-20046-00-00 GRANITE PT ST 11-24 167-023-0 50-733-20018-00-00 GRANITE PT ST 18742 09 167-042-0 50-733-20032-00-00 GRANITE PT ST 18742 10 178-096-0 50-733-20119-00-00 GRANITE PT ST 18742 31 179.017-0 50-733-20441-01-00 GRANITE PT ST 18742 34 181-022-0 50-733-20339-00-00 GRANITE PT ST 18742 40 195-005-0 50-733-20465-00-00 GRANITE PT ST 18742 52 MCARTHUR RIVER T 11N 169-095.0 50-733-20203-00-00 TRADING BAY UNIT D-20 173-001-0 50-733-20248-00-00 TRADING BAY UNIT K-17 SWANSON RIVER T 11 N R 11W SM 199-055-0 50-133-20489-00.00 SOLDOTNA CK UNIT 2436-04 180-106-0 50-133-20232-01-00 SOLDOTNA CK UNIT 42A-05 182-199-0 50-133-20363-00-00 SOLDOTNA CK UNIT 42B-05 100-146-0 50-133-10145-01-00 SWANSON RIV UNIT 14-15 162-034-0 50-133-10148-00-00 SWANSON RIV UNIT 14-22 172-007-0 50-133-20237-00-00 SWANSON RIV UNIT 24-33 162-030-0 50-133-10143.01-00 SWANSON RIV UNIT 41A-15 203-074-0 50-133-20523-00-00 SWANSON RIVER KGSF 3 II'ednesdnr, Junit rrh 14, :nnv j — j WV P CII �r L /'j /� (, �� "' n• /� f SFS �•n. �'or� u./!r+" Currcnl Dale of S(alus Slalus Surface Luralion.................................................... Lease(s)............................. SUSP 3/7/1988 1836 FNL 1954 FWL Sec 25 T 9 N R 9 W SM FEDA028407 SUSP 11/25/2007 2908 FNL 293 FEL Sec 21 T 2 S R 13 W SM FEE-C:IRI SUSP 8/11/1997 2428 FNL 1298 FWL Sec 13 T ION R 12W SM ADL0018761 SUSP 4/22/2006 2427 FNL 1303 FWL Sec 13 T ION R 12 W SM ADL0018761 SUSP 8/26/1997 2437 FNL 1303 FWL Sec 13 T ION R 12 W SM ADL0374044 SUSP 9/30/1997 2383 FNL 1368 FWL Sec 13 T ION R 12 W SM ADL0018761 SUSP 9/16/1989 834 FNL 676 FEL Sec 12 T ION R 12 W SM ADL0018742 SUSP 9/29/1988 1948 FSL 1979 FWL Sec 31 T 11N R 11W SM ADL0018742 SUSP 10/7/1988 1945 FSL 1982 FWL Sec 31 T 11 N R 11W SM ADL0018742 SUSP 9/20/1991 2012 FSL 1945 FWL Sec 31 T 11 N R 11 W SM ADL0018742 SUSP 4/21/1982 1948 FSL 1975 FWL Sec 31 T 11N R 11 W SM ADL0018742 SUSP 7/9/1995 730 FNL 682 FEL Sec 12 T ION R 12 W SM AOL0018742 SUSP 1/31/2007 672 FSL 1211 FWL Sec 6 T 8N R 13W SM ADL0018729 SUSP 4/20/2002 694 FSL 83 FEL Sec 17 T 9 N R 13 W SM AOL0017594 SUSP 9/22/1999 2003 FSL 575 FEL Sec 4 T 7N R 9W SM FEDA028997 SUSP 8/9/2006 1879 FSL 498 FEL Sec 5 T 7 N R 9 W SM FEDA028997 SUSP 6/21/2006 1823 FSL 572 FEL Sec 5 T 7 N R 9 W SM FEDA028996 SUSP 1/28/1997 360 FSL 1680 FEL Sec 16 T 8 N R 9 W SM FEDA028406 SUSP 10/5/1995 660 FSL 660 FWI. Sec 22 T 8 N R 9 W SM FEDA028406 SUSP 411/1993 932 FNL 2089 rWL Svc 4 T 7N R 9W SM FEDA028399 SI 8/26/1987 615 FNL 715 FEL Sec 15 T 8 N R 9W SM FEDA028384 SUSP 8/22/2007 1754 FNL 4030 FEL Sec 27 T 8 N R 9W SM FEDA028406 •_ z;'. " 7'e57'P� z rea //1- Operator Suspended and Shut In Wells UNION OIL CO OF CALIFORNIA Field Current Daic of Permit API Number Well Name Status 5tiltlls Surface Locotion.................................................... Lease(s) ................................... TRADING BAY 190-041-0 50-733-20302-01-00 TRADING BAY ST A-20RD SUSP 4/23/1990 1604 FSL 559 FEL Sec 4 1' 9 N R 13 W SM ADL0018731 /' a K MO -0 /ped Ij -// H'ednesdaY, Jnnang 14, 2009 20 AAC 25.1 10. Suspended Nvells (a) if allOWULl under 20 AAC 25.10.5. the COIl)17iiSS1011 will, upon aphl:c tion by t l� operator under (b) of this section, approve the suspension of a well i::' (1) the well (A) encounters hydrocarbons of sufficient quality and quantity to indicate that tine well is capable of producing in paying quantities, as reasonably demonstrated by wel tests or interpretive formation evaluation data; for purposes of this paragraph, "paying quantities" means quantities sufficient to yield a return in excess of operating costs; (13) is a candidate for redrilling; (C) has potential value as a service well; or (ll) is located on a pad or platform with active producing or service vvells; and (2) the operator justifies to the commission's satisfaction why the well should not be abandoned, and, if the well is not completed, why the well should not be completed; sufficient reasons include the (A) unavailability of surface production or transportation facilities; (13) imprudence of security maintenance of a completed well in a shut-in status; (C) need 1br pool delineation and evaluation to determine the prudence of pool development. (b) An Application for Sundry Approvals (Form 10-403) must be submitted 'o and approved by the commission before plugging operations are begun in a well for which suspciIsion is proposed, except that oral approval may be obtained from the commission if it is lbllowed within three days by the submission of an Application for Sundry Approvals for final approval by the commission. Approval will be conditioned as necessary to protect freshwater and hydrocarbon resources. An Application for Sundry Approvals must include (1) the reason for suspending the well and information showing that the applicable criteria for suspension under (a) of this section have been met; and (2) a statement of proposed work, including (A) information on abnonnally geo-pressured strata; (13) the manner ol' placement, kind, size, and location, by measured depth, of existing and proposed plugs; (C) plans for cementing, shooting, testing, and removing casing; (ll) if thu Applicction For Sundry Approvals is submitted after begi :tang work, the panic of the representative of the commission who provided oral approva, and the data; of the approval; and (E) other information pertinent to suspension of the well. (c) At the operator's request accompanying the submission, infonnation subrrit:ed to show that the applicable criteria for we]] suspension under (a) of this section have been met will be kept confidential (1) i'or the period specified under AS 31.05.035 (c), if the information is described in 20 AAC 25071 t b) ; or (2) for the time that the infonnation has value as a trade secret, if C.1c infoumlaticri is not described in 20 AAC 25.07 but is determined by the commission: to constitute a trade secret under AS 45.50.940 . (d) A well approved for suspension must be plugged in accordance -,with the requi:emcnts of 20 AAC; ?>_1.1.2. except that the requirements of 20 AAC 25.112(d) do not apply If (1) a wellhead is installed or the well is capped with a mechanical device to seal the opening; and (2) a bridge plug capped with 50 feet of cement or a continuous cement plug extending 200 feet within the interior casing string is placed at or above 300 feet below the surface; the commission will waive the requirement of this paragraph for a development well drilled from a pad or platform, if the commission determines that the level of activity on the pad or plattionn assures adequate surveillance of that development well. (e) Until a suspended well has been abandoned or re-entered, the operator shall maintain the integrity of the location, provide the commission with a well status report every five years, and clear the location in accordance with 20 AAC 25.170 a (2) or (b) or with 20 AAC 25..172(c) (2) or (d), as applicable. History: Eff. 4/2/86, Register 97; am 11/7/99, Register 152 Authority: AS -3 1.05.030 P a 5 �{ Of SARAH PALIN, GOVERNOR ALASS►A OIL AND GAS 333 W 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 January 28, 2009 FAX (907) 276-7542 CERTIFIED MAIL RETURN RECEIPT REQUESTED 7005 1820 0001 2499 6019 Dale Haines UNOCAL 3800 Centerpoint Dr. Ste 100 Anchorage AK 99503 Re: Notice of Revised Suspended Wells Regulations and Request for Verification of Suspended and Shut -In Well Information Dear Mr. Haines: OCT 0 3 2014 Enclosed are the Alaska Oil and Gas Conservation Commission's revised regulations regarding suspended wells (i.e., 20 AAC 25.110). Also enclosed is a list of suspended and long-term shut-in wells operated by UNOCAL. For each list, please verify the information for each well and provide any corrections by April 1, 2009. Location inspections required under 20 AAC 25.110 should be coordinated with Jim Regg at 907-793-1236 or jim.regg@alaska.gov. If you have any questions regarding this notice, please contact Tom Maunder at 907-793- 1250 or tom.maunder@alaska.gov. Sincerely, Cathy P. Foerster Commissioner Enclosures Postal CERTIFIED IVIAIL, RECEIPT o- O(Domestic Mail Only; . Insurance CoverageProvided) .n RIk 5 a V Postage ffi $0.59 SpS POST 9 r=1 Certified Fee $2.70 N O C-3 Return Receipt Fee S C (Endorsement Required) X2.20 C3 Restricted Delivery Fee C rU (Endorsement Required) $0.W n C13 LAK eccC `-q Total Postage & a, $5.49 01/28/ 0 Bent To Dale Haines UNOCAL r` Sheet Apt IJo.; or PO Box No. 3800 Centerpoint Dr. Ste 100 City, sYeie, ziw Anchorage AK 99503 mmmlill -.j ■ Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. ■ Print your name and address on the reverse so that we can return the card to you. ■ Attach this card to the back of the mailpiece or on the front if space permits. 1. Article Addressed to Dale Haines UNOCAL 3800 Centerpoint Dr. Ste 100 i Anchorage AK 99503 f i 2. Article Number (Transfer from service label) PS Form 3811, February 2004 AMRignature \ '��' X ' D �� `� E At .,,Received b (Printed Name) C. Qa lr if ' 0- V <-t'� lk' l D. Is delivery address different rom item 0 ❑ Y s 1 If YES, enter delivery address below: ❑ No S ice Type rtified Mail ❑ Express Mail ❑ Registered 043eturn Receipt for Merchandise ❑ Insured Mail ❑ C.O.D. 4. Restricted Delivery? (Extra Fee) ❑ Yes 7005 1820 0001 2499 6019 Domestic Return Receipt 102595-02-M-1540 Operator Suspended and Shut In Fells UNION OIL CO OF CALIFORNIA Field Current Date of Permit API Number Well Name Status Status Surface Location .................................................... Lease(s)................................... BIRCH HILL 165-001-0 50-133-10029-00-00 BIRCH HILL UNIT 22-25 SUSP 3/7/1988 1836 FNL 1954 FWL Sec 25 T 9 N R 9 W SM FEDA028407 DEEP CREEK 207-123-0 50-231-20031-00-00 HAPPY VALLEY B-12 SUSP 11/25/2007 2908 FNL 293 FEL Sec 21 T 2S R 13W SM FEE-CIRI GRANITE PT 196-045-0 50-733-20472-00-00 GRANITE POINT 52 SUSP 8/11/1997 2428 FNL 1298 FWL Sec 13 T ION R 12W SM ADL0018761 196-013-0 50-733-20470-00-00 GRANITE POINT 54 SUSP 4/22/2006 2427 FNL 1303 FWL Sec 13 T ION R 12W SM ADL0018761 197-145-0 50-733-20479-00-00 GRANITE POINT 55 SUSP 8/26/1997 2437 FNL 1303 FWL Sec 13 T ION R 12 W SM ADL0374044 167-057-0 50-733-20046-00-00 GRANITE PT ST 11-24 SUSP 9/30/1997 2383 FNL 1368 FWL Sec 13 T ION R 12 W SM ADL0018761 167-023-0 50-733-20018-00-00 GRANITE PT ST 18742 09 SUSP 9/16/1989 834 FNL 676 FEL Sec 12 T ION R 12 W SM ADL0018742 167-042-0 50-733-20032-00-00 GRANITE PT ST 18742 10 SUSP 9/29/1988 1948 FSL 1979 FWL' Sec 31 T 11 N R 11 W SM ADL0018742 178-096-0 50-733-20119-00-00 GRANITE PT ST 18742 31 SUSP 10/7/1988 1945 FSL 1982 FWL Sec 31 T 11 N R 11 W SM ADL0018742 179-017-0 50-733-20441-01-00 GRANITE PT ST 18742 34 SUSP 9/20/1991 2012 FSL 1945 FWL Sec 31 T 11 N R 11 W SM ADL0018742 181-022-0 50-733-20339-00-00 GRANITE PT ST 18742 40 SUSP 4/21/1982 1948 FSL 1975 FWL Sec 31 T 11 N R 11 W SM ADL0018742 195-005-0 50-733-20465-00-00 GRANITE PT ST 18742 52 SUSP 7/9/1995 730 FNL 682 FEL Sec 12 T ION R 12 W SM ADL0018742 MCARTHUR RIVER 169-095-0 50-733-20203-00-00 TRADING BAY UNIT D-20 SUSP 1/31/2007 672 FSL 1211 FWL Sec 6 T 8 N R 13W SM ADL0018729 173-001-0 50-733-20248-00-00 TRADING BAY UNIT K-17 SUSP 4/20/2002 694 FSL 83 FEL Sec 17 T 9 N R 13W SM ADL0017594 SWANSON RIVER 199-055-0 50-133-20489-00-00 SOLDOTNA CK UNIT 2438-04 SUSP 9/22/1999 2003 FSL 575 FEL Sec 4 T 7 N R 9 W SM FEDA028997 180-106-0 50-133-20232-01-00 SOLDOTNA CK UNIT 42A-05 SUSP 8/9/2006 1879 FSL 498 FEL Sec 5 T 7 N R 9 W SM FEDA028997 182-199-0 50-133-20363-00-00 SOLDOTNA CK UNIT 4213-05 SUSP 6/21/2006 1823 FSL 572 FEL Sec 5 T 7 N R 9 W SM FEDA028996 100-146-0 50-133-10145-01-00 SWANSON RIV UNIT 14-15 SUSP 1/28/1997 360 FSL 1680 FEL Sec 16 T 8 N R 9 W SM FEDA028406 162-034-0 50-133-10148-00-00 SWANSON RIV UNIT 14-22 SUSP 10/5/1995 660 FSL 660 FWL Sec 22 T 8 N R 9 W SM FEDA028406 172-007-0 50-133-20237-00-00 SWANSON RIV UNIT 24-33 SUSP 4/1/1993 932 FNL 2089 FWL Sec 4 T 7 N R 9 W SM FEDA028399 162-030-0 50-133-10143-01-00 SWANSON RIV UNIT 41A-15 SI 8/26/1987 615 FNL 715 FEL Sec 15 T 8 N R 9 W SM FEDA028384 203-074-0 50-133-20523-00-00 SWANSON RIVER KGSF 3 SUSP 8/22/2007 1754 FNL 4030 FEL Sec 27 T 8 N R 9W SM FEDA028406 Ifednesday, January 14, 2009 Operator Suspended and Shut In Wells UNION OIL CO OF CALIFORNIA Field Current Date of Permit API Number Well Name Status Status Surface Location .................................................... Lease(s)................................... TRADING BAY 190-041-0 50-733-20302-01-00 TRADING BAY ST A-20RD SUSP 4/23/1990 1604 FSL 559 FEL Sec 4 T 9 N R 13 W SM ADL0018731 Wednesday, January 14, 2009 ALASKA OIL AND GAS CONSERVATION COMMISSION t. Operations performed: dperation shutdown~ ' Stimulate; Plugging: Perforate: I Pull tubing: X Alter casing: Repair well: Other: X 2, Name of Operator ' 5, Type of Well: 6. Datum elevati0~ (DF or KB) '-- Union Oil of California (Unocal) Development: X 105' above MLLW feet m , 3. Address Exploratory: 7. unit or Property name -- Strafigraphic: P,O, Box 196247 Anc, horage, AK 99519 Service: Granite Point Field 4. Location of well at surface " 8. Well numbS" , 2383' S & t368' E from NW Corn. Sac. 13, T10N, Rt2W, SM 11-24 At top ~3f productive intmval 9. Permit number/approval number 3127' S && 646' W f/surface location 87-0057 At effective depth 10. APl number ...... 50-133-201)46 At total depth ~ 1, Field/Pool 2950'$ & '1108' W f/Sun'ace Location from NE Comer, Sec. 24, TION, R12W Granite Point Field/Middle Kenai -12. Present well oondition sun{mery ..... Tole] depth: measured 11,800 feat Plugs (measured) Cmt Plug (11 Bbls) 9,440', 9,585' true vertical 11,068 feet Cemen~ Retainer 9.585' - 9. S87' Cmt Ptug (47 Bbls) 9,587'- 11,16fi' Effective depth; measured 9,440 feet Junk (measured) true vertical 8,780 feet 3-1/2" Tbg Fish 9,835', 10,0t0' Casing Length Sire Cemented Measured depth T~'ue vertical depth " Structural Conductor 18" 70.59 600 sx 635' 633' Surface 13-3/8" 61 1900' sx 4030' 3798' Intermediate Production 9-5/8" 40 to 47 515' sx 10,086' 9415' Liner 7" 326' 963'-1 t798' 9298'-11068' Pedoration depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and meaeumd depth) 13. ,Stimulation or cemen£ squeeze summary In.tervals treated (measured) Treatment de'scriptlon including volumes used and final pressure '~1'4,. RepreSentative Dall~ Avera~le Pmdu~qn er !.niection Data "' OiFBBL Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation g/1/1996 47 215 17 Subsequent to operation 10/1i1996 Shut-in since 10/96 15. Affechments: 16. Status of well classification as: Cop/es of Logs and Surveys run: DaVy Report of Well Operations: X Oil: Gas: Suspended; X Sewice; ~'~', I hereby ~ertify that the foregoing is true and correct to the best of"~; knowledge: .... Dan Williamao~ Form t 0.4o4 Rev 06/t SUBMIT IN DUPLICATE 3/~ 'd OgZg'oN ,A~lnq -lunn~ln J^lw~n,n~ ccc, ,~ ,~n,", STATE OF ALASKA ~ ALASKA O-~.-.AND GAS CONSERVATION CO,v,MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: Pull tubing: X Alter casing: Repair well: Otl~er: X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil of California (Unocal) Development: X 105' above MLLW feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 Service: Granite Point Field 4. Location of well at surface 8. Well number 2383' S & 1368' Efrom NW Corn. Sec. 13, T10N, R12W, SM 11-24 At top of productive interval 9. Permit number/approval number 3127' S && 646'W f/surface location 67-0057 At effective depth 10. APl number 50-133-20046 At total depth 11. Field/Pool 2950'S & 1108'W f/Surface Location from NE Comer, Sec. 24, T10N, RI2W Granite Point Field/Middle Kenai 12. Present well condition summary Total depth: measured 11,800 feet Plugs (measured) Cmt Plug (11 Bbls) 9,440'- 9,585' true vertical 11,068 feet Cement Retainer 9,585' - 9,587' Cmt Plug (47 Bbls) 9,587'- 11,165' Effective depth: measured 11,108 feet Junk (measured) true vertical 10,414 feet 3-1/2" Tbg Fish 9,440' - 10,010' Casing Length Size Cemented Measured depth True vertical depth Structural 18" 70.59 800 sx 635' 633' Conductor 13-3/8" 61 1900' sx 4030' 3798' Surface 9-5/8" 40 to 47 515' sx 10,086' 9415' Intermediate Production Liner 326' 963'-11798' 9298'-11068' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) I{Ei:EIVED ..... 13. Stimulation or cement squeeze summary JUN ~ 0 1999 Intervals treated (measured) Alaska 0ii & Gas Cons. C0mmissi0r, Treatment description including volumes used and final pressure Anchorage 14. Representative Daily Avera.qe Production or Iniection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 9/1/1996 47 215 17 0RIG!NAL Subsequent to operation 10/1/1996 Shut-in since 10196 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: Gas: Suspended: X Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: ,ed.'~ ~~ Title: Drilling Manager Date: 6/30/99 Da.n Williamson · m 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE GRANITE POINT PLATFORM WELL # 11-24 . RKB = 114.75"; 43' Rig Floor to Wellhead CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 13-3/8 61 K-55 BTC Surf 4,030 9-5/8 40-47 N-80/S-95 BTC Surf 10,086 7" 29 P- 110 X-line 9,963 11,798 Tubing Fish 3-1/2" 9.2 L-80 SC-BTC 9,440 10,010 NO. ITEM COMPLETION DETAIL DEPTH Top Cement Plug (11 BBLS) 9,440'-9,585' HES EZ-SV Cement Retainter 9,585' Bottom Cement Plug (47 BBLS ) 9,587'-11,165' Otis "XO" Sliding Sleeve w/valve 9,836' Fish: Wash-pipe Shoe (L=4.35', OD = 8-1/2", ???? ID = 7-1/8") Otis "XO" Sliding Sleeve w/valve 10,480' TOF @ 9,824' TOL @ 9,963' 4 5 Note: Otis "Q" Profile Nipple (ID = 2.635") 10,699' Top of tubing fish is @ 9,835'. Cement top is calculated. Hole and bad spots in casing from 9,722' to 9,838'. See morning reports for more detail. PDTD = 9,440' MAX HOLE ANGLE _+ 25 ° ABANDONED PERFORATION DATA A¢oum. Date Zone Top Btm Amt SPF Last Opr. Present Condition 9,765' 9,766' 1' 8 1/6/68 Block cmt sqz 28 cuff of class "G". tested to 5,000 psi. C2 9,836' 9,866' 30' 4 1/10/68 Perf f/Production 9,950' 9,951' 1' 4 1/3/68 Pressure tested to 5,000 psi, no break down C.5 1..0,095' 10,130' 35' 4 1/10/68 Perf f/Production C5 10,150' 10,240' 90' 4 1/10/68 Perf f/Production C6 10,315' 10,350' 35' 4 1/10/68 Perf f/Production 10,400' 10,401' 1' 4 1/3/68 Pressure tested to 5,000 psi, no break down C7 10r535' 10,560' 25' 8 10/25/68 Perf f/Production C7 10,580' 10r660' 80' 8 10/25/68 Perf f/Production C7 10,675' 10.,700' 25' 8 10/25/68 Perf f/Production 10,750' 10,751' 1' 4 1/2/68 Pressure tested to 5,000 psi, no break down C9 11,135' 11,165' 30' 4 12/30/67 Isolated below retainer @ 11,108' ,,,, O:\OOE\OOEFields\GPF~Granite Point\Wells\Gp 11-2A~Schematics\GP 11-24 Final 9-30-97.doc REVISED: 10/23/97 DRAWN BY: MWD GRANITE POINT 11-24 WORKOVER 9~9~97 TO 9~30~97 DAY 1-4 (9/9-9/12/97) 9-5/8" CSG @ 10,086' 7" LNR @ 9,963' TO 11,987' KILL WELL WITH FILTERED INLET WATER. WELL ON VACCUUM. ND TREE NU BOPE. PULL TBG HGR LOOSE. ClRC WELL. (TAKING 12-18 BBL/HR). Cut S.S. At 9,669 WLM. ClR BTMS UP TO CLEAR GAS. LAY DOWN MANMANDRELL HANGERS. DAY 5-10 (9/13-17/97) 9-5/8" CSG @ 10,086' 7" LNR @ 9,963' TO 11,987' FISHED 2-7/8" S.S. POOH. HAD SOME TROBLE WORKING BU COUPLINGS AT 9550 AND 9,583'. WASHED DOWN TO 9,600'. GAS UNITS UP TO 1,800 GETTING SAND & COAL IN RETURNS. ClR 40BBL HIGH VIS SWEEP. DAY 11-18 (9/13-19/97) 9-5/8" CSG @ 10,086' 7" LNR @ 9,963' TO 11,987' MILL AND ATTEMPT TO GET THRU SLEEVE @ 9,732'. RIH WITH 2.7" JET CUTTER. TIE IN & SEVER 3-1/2" TBG @ 9,741'. JAR ON PACKER 80K OVER TO 130K OVER. MOVING PKR 15'. DAY 19-23 (9/20-24/97) 9-5/8" CSG @ 10,086' 7" LNR @ 9,963' TO 11,987' MILL ON BAD SPOT @ 9,781'. WASH & REAM FROM 9,668-9,789'. PUMP 30 BBL HIGH VIS SWEEP. GETTING 10BBLS OF ¼" COAL IN RETURNS. DAY 24-27 (9/25-27/97) 9-5/8" CSG @ 10,086' 7" LNR @ 9,963' TO 11,987' CLEANED UP TOP OF FISH AND WORKED DOWN TO 9,835'. HAVING TROUBLE GETTING OFF TOP OF FISH. RECOVERED 2.5" SLIDING SLEEVE. SUSPEND WELL. DAY 24-27 (9/28-30/97) 9-5/8" CSG @ 10,086' 7" LNR @ 9,963' TO 11,987' SET EZSV AT 9,585' DPM AND ESTABLISH INJECTION. BATCHED UP 75 BBLS OF CMT. PUMP ABANDONMENT SQUEEZE, 47 BBL CMT BELOW EV-SV AT A STARTING RATE OF 2,000 PSI AT 5 BBLS/MIN AND INCREASED TO 3,500 PSI AT .5 BBLS/MIN. POH TO 9,366' AND REVERSED OUT EXCESS CMT. INSTALL TREE AND TEST SAME AGAINST CMT PLUG TO 250/3000 PSI. TESTED OK RELEASED RIG. "-'" STATE OF ALASKA ' ~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type ~,f Request: Abandon: Suspend: Operation shutdown: Re. enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate:' Change approved program: x Pull tubing: Variance: x Perforate: Other: x 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil of California (Unocal) Development: 105' above MLLW feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: -, P.O. Box 196247 Anchorage, AK 99519 Service: x Granite Point Field 4. Location of well at surface 8. Well number 2383' S & 1368' E from NW Com. Sec. 13, T10N, R12W, SM 11-24 At top of productive interval 9. Permit number 3127' S && 646'W f/surface location (~ ~ "(~ O~ 7 At effective depth 10. API50_~.33,,394~lnumber 7 33-' ~ 0 At total depth 11. Field/Pool 2950'S & 1108' W f/Surface Location from NE Comer, Sec. 24, T10N, R12W Granite Poi_n.t. Fi.....~d/.lyl,~e~K~n~ ~,,~. 12. Present well condition summary R ~'1~'~!1 V f~ Total depth: measured 11,800 feet Plugs (measured) . true vertical 11,068 feet SEP 9 1997 Effective depth: measured 11,108 feet Junk (measured) Alasl~ ~ & ~as,C0ns. uotu~d~s~." true vertical 10,414 feet Casing Length Size Cemented Measured depth True vertical depth Structural 18' 70.59 800 sx 635' 633' Conductor 13-3/8' 61 1900' sx 4030' 3798' Surface 9-5~8' 40 to 47 515' sx 10,086' 9415' Intermediate Production Liner 7" 326' 963'-11798' 9298'-11068' Perforation depth: measured 9765'-9766' SQZ'; 9836'-9866'; 9950'-9951'; 10,095'-10,130'; 10,150'-10,240'; 10,315'-10,350'; true vertical 9095'-9096'; 9167'-9197'; 9285'-9286'; 9482'-9570'; 9642'-9677'; 9725'-9726'; 9855'-9883'; 9900'-9983'; 9900'-9983'; 9996'-10,019'; 10,070'-10,071'; 10,443'-10,473' Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) ORI$1 L 13. Attachements Description summary of proposal: x Detailed operations program: BOP sketch: See Procedure , Directional Program 14. Estimated date for commencing operation 15. Status of well classification as: 16. If proposal well verbally approved: Oil: x Gas: Suspended: Name of approver Date approved Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: Dale Haines /"~ z~,. c.. ?'~1 c~ Title: Drilling Manager Date: 9~5~97 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval No. Plug integrity BOP Test ~ Location clearance I . ~'~'" Mechanical Integrity Test ~ Subsequent form required 10- /.~¢0 ~ -- ~ 0o9~ Original Signed By ,,~o'~e?,,~* David W. Johnston ~,~ ~_/? Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE UNOCAL ) Granh~ ~oint Field GP #11-24 Workover Procedure ReVised 9/8/97 Revision//2 Objective: Convert GP 11-24 to a Zone B, Zone B'l, and Zone C 10,000 psi water injector. I. Prepare Well for Workover: 1. MIRU PTA slickline unit. . Pull all CX valves and close sliding sleeves in both the long and short strings. Leave the bottom sliding sleeve, of both robing strings, open; so that the well can be killed. 3. RD PTA. 4. Record all casing pressures and robing pressure prior to pumping. 5. Bleed off gas fi.om annulus. Fill annulus with F1W. Note: Do not exceed 4,000 psi on 9-5/8" casing. 6. Bullhead 90 BBLS of Filtered Inlet Water (FIW) down the short string. 7. Bullhead 100 BBLS of FIW down the long string. . Circulate FIW down the long string, through the robing hole ~ 8,970' and out the 3-1/2" X 9-5/8" armulus--taking returns to production. Verify well is dead. 9. Record final casing pressures and tubing pressures. 10. Call-out FMC wellhead hand. Set BPV in robing hanger. 11. Note: A13-5/8" 5M X 11" 10M tubing spool and 10M Adapter Flange will be installed during workover. This equipment is being air fi.eighted fi.om Woodgroup Pressure Control in Lafayette. Prepare to change out 9-5/8" casing valves if required. Move rig from GP 22-13RD2 over GP 11-24. ND tree. NU 13-5/8" #13 Hub X 13-5/8" Flange XO spool and 13-5/8" BOPE. Note: BOP configuration fi.om top to bottom: 1) annular preventer, 2) pipe rams, 3) blind rams, 4) drilling spool, and 5) VBR's. Notify AOGCC personnel 24 hours prior to conducting test. Notify state for MIT. 12. Test annular preventer to 250/3,500 psi and both pipe rams to 250/5,000psi. GP 11-24 WOproc l.doc Page 1 of 6 09/08/97--2:24 PM UNOCAL ) Granit~ ~oint Field GP #11-24 Workover Procedure Revised 9/8/97 Revision #2 II. Pull Existing Dual Gas Lift Completion: 1. RU GBR tubing crew and handling tools. Note: The 3-1/2" Armco Seal-lock tubing uses Buttress handling tools. Note: Weatherford will be the fishing company for GP 11-24 and GP 24-13RD 2. RIH and MU 3-1/2" short string landing joint. . PU and release tubing hanger and pull short string seal assembly out of RDH packer 9,693 '. Note: If the short string doesn't release, be prepared to cut tubing using APRS. If a cut is made and the short string will not pull out, have handling tools on standby to pull dual string. We will also need dual rams. 4. Circulate one complete tubing and casing volume with FIW. Verify well is dead. 5. POOH and laying down 3-1/2" tubing. Check all tubing for NORM. , . RIH and MU 3-1/2" long string landing joint. PU 60,000 lbs over string and top drive weight to release RDH packer ~ 9,693'. 8. Circulate one complete tubing and casing volume with FIW. Verify well is dead. 9. POOH and laying down 3-1/2" tubing. Check all tubing and jewelry for NORM. 10. PU 6" used bit. Runbit inthe hole on ddllpipe and clean out the 7" liner to 11,108'. 11. Circulate a Hi-Vis sweeP. 12. POOH with bit. GP 11-24 WO proc l.doc Page 2 of 6 09/08/97--2:24 PM UNOCAL( GramL~ Point Field GP #11-24 Workover Procedure Revised 9/8/97 Revision #2 Contingency for the RDH Not Releasing: Note: Only one fishing attempt will be made to retrieve RDH packer. No attempt to mill the packer will be made. If the packer is not retrieved, we will set Halliburton's 9-5/8" packer above the existing RDH packer ~ 9,693'. We already have decided we can live without the scab liner. 1. RU APRS wireline unit on the long string. . RIH with chemical cutter to ~ 9,630 make sure cutter is in the middle of a robing joint. Cut 3-1/2" tubing. 3. POOH with cutter and RD APRS. 4. POOH with long string tubing. 5. MU the following BHA: 6. RIH with overshot and engage tubing stub ~ 9,630'. 7. Attempt to jar RDH packer loose. GP 11-24 WO proc 1.doc Page 3 of 6 09/08/97--2:24 PM UNOCAL ) Granit~ doint Field GP #11-24 Workover Procedure Revised 9/8/97 Revision #2 IV. Change out Tubing Spool. o MU the following BHA: 12 stands of 5" 19.5 lb/f[ drillpipe HES 9-5/8" 40 lb/f[ RTTS HES Storm valve MU to RTTS. 2. RIH with RTTS to 360'. Rotate to the right and set RTTS. 3. Rotate to the left and release from RTTS. 4. Pressure test casing and RTTS to 3,000 psi. 5. POOH. 6. ND and stand-back BOP stack. . NU new 13-5/8" Tubing spool (13-5/8" 5M CIW #13 Clamp hub, BX-160, bottom X 11" 10M, BX-158, Flange Top). 8. NU 11" Bx-160 Flange x #13 Clamp XO spool, riser and BOP. Note: BOP configuration from top to bottom: 1) annular preventer, 2) pipe rams, 3) blind rams, and 4) drilling spool. 9. Test BOP. 10. RIH and rotate 20 tums to right, pick-up and release RTTS. 11. POOH and LD RTTS. GP 11-24 WO Proc l.doc Page 5 of 6 09/08/97--2:34 PM UNOCAL ) GranlL~ Point Field GP #11-24 Workover Procedure Revised 9/8/97 Revision #2 V. Run Water Injection string. . RIH with the Completion string as follows: HES Straight Lot Seal Assembly (21 ft long, 4.75" OD, 3.06" ID) 3-1/2" 9;2 lb/ft L-80 Special Clearance Buttress tubing 3-1/2" Buttress x 3-1/2" 8rd pup joint Woodgroup 11", 1 OM Extended Neck Tubing Hanger ( 3-1/2" 8rd top and bottom with Cameron BPV profile) Note: Replace FMC tubing hanger elastomers 2. Stop RIH above BWD packer ~ 9,640'. 3. Space-out so that the tubing has 10,000 lbs down on packer 4. Reverse circulate Tretolite CRW 132 corrosion inhibitor ~ 1.0% into the annulus. Note: Ensure the entire seal assembly is inside the SC-2P seal-bore 5. While circulating stab seals into BWD packer. 6. Pressure up to 500 psi and test seals against the formation. 7. Land FMC tubing hanger with 10,000 lb of compression set down on packer. 8. Run-in tie-down bolts. 9. RU chart recorder. 10. Pressure test 9-5/8" casing, straddle packer assembly, 7" casing, SC-2P packer, and seals to 3,000 psi for 30 minutes. 11. Set BPV and ND BOPE 12. Pull BPV and NU tree. 13. Pull BPV and install two-way check. Test tree to 250/5,000 psi. Note: When the 10,000 psi tree arrives it we be installed and pressure tested to 10,000 psi. GP 11-24 WO proc 1.doc Page6 of 6 09/08/97--2:38 PM UNOCAL ) RKB to TBG Hngr = 41' Granite Point Well # 11~,, Complete. 10/30/68 CASING AND TUBING DETAIL SIZE ~,-r GRADE CONN ID TOP BTM. 13-3/8" 61 K-55 Butt t 2.515 Surf. 4030' 9-5/8" 40 to 47 N-80 & S-95 Butt 8.681 Surf 10,086' 7" 29 P-110 X-Line 6.184 9963' 11,798' Tubing: LS 3-1/2" 9.3 N-80 Seal Lock 2.992 0' 9702' SS 3-1/2" 9.3 N-80 Seal Lock 2.992 0' 10.699' 11 WSO C2 WSO C5 C5 JEWELRY DETAIL NO. Depth ID Item 41 A 250' B 2298' C 3765' D 4742' E 5567' F 6356 G 6971' 7678' 8232' 8736' K 9693' L 9701' M 9702' 2,635 I .236' 2 2272' 3 3727' Otis type CX GLM 4 4743' Otis type CX GLM 5 5582' Otis type CX GLM 6 6343' Otis type CX GLM 7 6988' Otis type CX GLM 8- 7707' Otis type CX GLM 9 8253' Otis ty~e CX GLM I0 8742' Otis type CX GLM I 1 9693' Otis RH Dual Pkr. 12 9742' Otis "XO" Sldg Sire 13 9836' Otis "XO" Sldg Slvc 14 10,480' Otis 'XO" Sldg Slvc 15 10,699' 2.635 Otis "Q" Profile Nipple Can~ron DCB Dual 3-1/2" Tubing hangers. SHORT STRING 3-1/2" Otis Flow Coupling ,~ Ball Valve Nipple Otis ty~e CX GLM CX pulled, slve closed Otis t~e CX GLM CX pulled, slvc closed Otis type CX GLM CX pulled, slve closed Otis type CX GLM CX oullcd, slve closed Otis type CX GLM CX ~ulled. slve closed Otis type CX GLM (C/O to Camco center set GLM Jtme 1995) Otis type CX GLM (C/O to Camco center set GLM June [995) Otis type CX GLM (C/O to Camco center set GLM June 1995) Ous type CX GLM (C/O to Camco center set GLM June 1995) Otis Riff Dual Plo-. Otis "Q" Profile Nipple Catcher sub LONG STRING 3-1/2" Otis Flow Couphng .,-' Ball Valve Nipple Otis ty~e CX GLM VaNe pulled in 1977 Valve pulled in 1977 Valve putlcd in 1977 Valve pulled in 1977 Valve pulled in 1977 Vaive pulled in 1977 Valve pulled in 1977 Valve pulled in 1977 Valve pulled in 1977 14 C6 WSO C7 C7 15 WSO ,-...~ KB ELEV = 101' TD = 11,800' PBTD = 11,108' MAX HOLE ANGLE = 250 Zone i C5 ~ C7 ; C7 ; Wireline Tags SS Tagged obstrucuon w/1.25" OD LIB ~, 8244' LS Tagged obslxucUon w/2.25"OD bailer ~ 8970' 2/2/94 1/30/94 PERFORATION DATA ~ ! Ac. cum. I Date TOO Btm Amt i SPF ! LastOpr. 9,765' 9,766' 1' 9,950' 9,951' 1' + 4 ! 1/3/68 10,095' 10,130' 35' i 4 i 1/10/68 10,150' 10.240' 90' ' 4 1110168 10,315' 10.350' "35' i 4 1110168 10,400' 10,401' '" 1' 4 i 113168 10,535' 10.560' ' 25' i 8 I 10/25/68 10,580' 10,660' ' 80' ; 8 ! 10/25/68 10,675' 10,700' 25' i 8 i 10/25/68 10,750' 10.751' 1' i 4 i 112/68 11,135' 11.165' ' 30' ; 4 i 1Z/30/67 Present Condition Block cmt saz 28 cuff ol class "G". itestea t~ 5.000 psi. Perf f/ProduclJen Pressure tested to 5.0(]0 psi. no I break oow~ iPerf t/Production Peal f/Pro~luctJo~ t Perf fl Production Pressure tested to 5,000 psi, no break Oow~ iPed f/Producl~o~ Perf fl Pn:xtucl~on IPerf f/Producbon Pressure tested to 5,000 psi, no Iselate~ DaOW retainer @ 11,108' 11-24.DOC REx, qSED: 9/8/97 DRAWN BY: SLT GRANIrE POINT PLATFORM WELL # 11-24--Water Injector RKB = 114.75"; 43' Rig Floor to Wellhead CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 13-3/8 61 K-55 BTC Surf 4,030 9-5/8 40-47 N-80/S-95 BTC Surf 10,086 7" 29 P-110 X-line 9,963 11,798 Tubing 3-1/2" 9.2 L-80 SC-BTC Surf 10,010 TOL @ 9,963 PDTD = 11.108' MAX HOLE ANGLE +_. 25 ° 3, 4 5 6 7 8, 9 10 NO. ITEM JEWELRY DETAIL DEPTH 1 Woodgroup 10M psi Tubing Hanger 41 (8rd threads) 2 3-1/2" 9.2 lb/ft 8rd x Buttress XO pup joint 3 IdES No-Go 21 ft Seal Assembly 4 HES 9-5/8" BWD Peranent Packer 9.640 5 HES Seal-bore Extension (24 ft ID = 4.0") 6 HES Millout Extension (8' ID = 4,276") 7 X-Nipple (ID = 2.813") 8 HES No-Go 11 ft Seal Assembly 9 HES 7" BWD Permanent Packer 10,000 10 HES Seal-bore Extension (8 ft ID = 4.0") PERFORATION DATA i Accum. Date Zone I Top Btm Amt SPF Last Opr. Pr~t Condition 9,765' 9,766' 1' 8 1/6/68 9,836' 9,950' 10,095' 10,150' 9,866' 9,951' 10,130' 10,240' 35' 4 90' i 4 35' 4 1/10/68 1/3/68 1 /10/68 1/10/68 Block cmt sqz 28 cuff of class 'G'. tested to 5,000 psi. Perf f/Production Pressure tested to 5,000 psi, no break clown I Perf f/Production Perf f/Production Per/f/Production C6 ~ 10,315' 10,350' 1/10/68 i 10,400' 10,401' 1' 4 113/68 i Pressure tested to 5,000 psi, no t break clown C7 10,535' 10,560' 25' 8 10/25/68 IPerf f/Production C7 10,580' 10,660' 80' 8 10/25/68 IPerf f/Production C7 10,675' 10,700' 25' 8 10/25/68 !Perf f/Production 10,750' 10,751' 1' = 4 1/2/68 !Pressure tested to 5,000 psi, no I break clown C9 ' 11,135' 11,16S' 30' 12/30/67 ~ 4 Ilsotated betow retainer @ 11,108' F:\GROUPS~DRII.I.ING\SCH]EMATI~GP\GPI~GP 11-24 Proposed 2.doc REVISED: 9/8/97 DRAWN BY: MWD HALLI B U RTON Halliburton Energy Services Proposed Completion Guide r~ Prepared For: Unocal Oil & Gas Attention Of: Mitch Datum Date: 9/5/97 Field: Granite Point Well Name: GP #11-24 Location: Granite Point Platform Cook Inlet, AK Casing: 9 5/8" 40# & 47# Liner: 7" 291/ Tubing: 3 1/2" 9.2tt L-80 BTC Item # 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 Description 3 1/2" 9.211 L-80 BTC Tubing to Surface No Go Seal Assembly (Locator, Seal, Ext., Seal, Ext., Seal, Ext., Seal, Ext., Seal, Ext., (4) Seals.) 9 5/8" 36# - 59.4# 'BWD' Permanent Packer Seal Bore Extension Seal Bore Coupling Seal Bore Extension Seal Bore Coupling Seal Bore Extension Seal Bore Coupling Millout Extension Tubing Adapter 3 1/2" 9.211 L-80 BTC Tubing 2.813" 'X' Landing Nipple 3 1/2" 9.2# L-80 BTC Tubing No Go Seal Assembly (Locator, Seal, Ext., Seal, Ext, Seal, Ext., (2) Seals.) 7" 23tt - 32# 'BWD' Permanent Packer Seal Bore Extension Entry Guide * Verbally approved by Mitch Damm 9~4~97 Prepared by Morris Cox Anchorage, AK (907) 344-2929 I.D. O.D. Lenqth Depth 2.992 3.500 4.750 3.060 21.00 4.000 8.120 4.00 4.000 4.750 8.00 4.000 5.250 1.00 4.000 4.750 8.00 4.000 5.250 1.00 4.000 4.750 8.00 4.000 5.250 1.00 4.276 5.000 8.00 2.992 5.250 1.00 2.992 3.500 270.00 2.813 4.250 1.50 2.992 3.500 60.00 4.750 3.060 11.00 4.000 5.875 4.00 4.000 4.750 8.00 Alasxa Re<j~on April [6, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99504 Attn: Ms. Elaine Johnson Dear Ms. JohnSon: I have attached surface survey locations of the "Legs" and conductors for the four platforms in the Trading Bay Unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor but I hope this will meet your needs. Yours very truly, Gar~. S. Regional Drilling Manager GSB/lew GRANITE POINT PLATFORM FROM NW CORNER OF SECTION 13, TION, R12W CONDUCTOR Leg#1 · Leg#2- Leg#3' Leg#4' "Y" COOR. "X" COOR. WELL # FSL 2,544,566.00 263,297.33 2,544,572.08 263,294.75 13-13 2371 2,544,572.41 263,299.33 44-14 2373 2,544,569.75 263,302.99 33-14 & RD 2371 2,544,565.34 263,303.99 31-23 2366 2,544,561.34 263,302.08 31-.14 & RD 2362 1 & 2 2,544,599.42 263,297.83 44-11 & RD 2360 2,544,560.67 263,293.33 Open 2,544,564.50 263,290.83 12-24 2363 2,544,569.00 263,291.42 32-23 & RD#2 2368 2,544,610.00 263,364.00 Compressors 2,544,543.33 263,408.00 -2,544,548.16 263,403.42 31-13 2382 2,544,549.91 263,407.59 22-13 ' 2379 2,544,548.66 263,412.00 MUC#I-1 2391 2,544,544.99 263,414.41 MUC#I-2' 2386 2,544,540.42 263,413.91 32-13, 33-13 2390 2,544,537.25 263,410.58 24-13 & RD 2392 2,544,537.00 263,406.09 42-23X, 31-23 2380 2,544,539.58 263,402.42 11-24 2383 2,544,544.08 263,401.42 11-13 2379 2,544,499.58 263,341.33' FEL 1267 1262 1258 1256 1258 1261 1269 '1269 1370 1375 1379 1381 1379 1376 1371 1368 1375 Form 1C~403 /'"~\ Subml t *'1 ntentions" in Triplicate REV. 1-~10~73 & "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.) O,L I-J-I GAS F'-I WELL~ WELL' ' OTHER 2. NAME OF OPERATOR UNION OIL CO. Of CALIFORNIA APl NUMERICAL CODE 50-133-2C046 6. LEASE DESIGNATION AND SERIAL NO. ADL 18761 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME UNION -MOBIL STATE #1. 3. ADDRESS OF OPERATOR 9. WELL NO. P.O. BOX 6247, ANCHORAGE, ALASKA 99501 GPS 11-24 10, FIELD AND POOL, OR WILDCAT corner, Sec.13, T1ON, R12W, S.M. 4. LOCATION OF WELL At surface 2383'5 & 1368' E from N.W. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) KB 95, above MSL z4. Check Appropriate Box To Indicate Nature of Notice, Re ..GRANITE POINT - MIDDLE KENAI ll. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE} SEC. 24, T1ON, R12W, S.M. ].2. PERMIT NO, 67-57 )or=, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) CHANGE OF PULL OR ALTER CASING MU LTI PLE COMPLETE ABANDON* CHANGE PLANS D~P~Eg~TOR SUBSEQUENT REPORT OF: WATER SHUT-OFF r'~ REPAI RING WELL FRACTURE TREATMENTH 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 13ertinent details, and give pertinent dates, Including estimated date of starting any proposed work. FROM: TO' MOBIL OIL CORP. UNION OIL CO. OF CALIFORNIA RECEIVED hereby certify that the foregoing Is true and correct S,GNE~"'~"L'~----'~~f['~ T,TLE DISTRICT DRILLING SUPT. . DATE (This spa-Ce-TorSt~te office use) CONDIT IONS OF~a~PPROVAL., I F ANY: TITLE See Instructions On Reverse Side Approved Copy, Returned DM-12 A. P. !. CODE ' 50..-+-'e~'-eee,~ State of Ataska Re~ease O~ Department of Natural Resources DIVISION OF MINES AND MINERALS Sec. (13) 24 Petroleum Branch T. · -ION R. - 12.'.{ S Meridian INDIVIDUAL WELL RECORD ---- - Permit No. 67-57 Issued 9-25-67 Operator Mobil Oil Corp. Lease No-~--316~ 'i876! o r 0wne r __U_n~,pn-~_.fob~_. ! _ Stg..t Location (Surface) 2383'FNL & 1368' FR~L Sec. 13 L.~-,~ , m .,._ _ . . J- _1 _ Well No. 11-24 Area ........ ~Loc. (Bottom) Granite Point 2112' FNL &;623' Fl,~ Sec. 24 PBD !!, 108 . Total Depth 1i,$00 Spud Date 10-5-67 Drilling Ceased Suspended__.= -. Completed Abandoned 1-21-68 IP i05.9'K.3. - Elevation_=_ 7-mLN ...... 4172 B/D, Grav 41.1 APl Cut 0.4 % Gas 3104 MCF/D, Bean 176 /64 CP Perf: psi, TP 125 ~o.~si Casing: Si ze 13 3/8"~5oe 40'30~" ~ i0,250'-240';!0315'-50'] ~.'OVC .?~O6' 1700+350 7. ~'~-5~[5-i-'~60~i-'i-~;580'~660'-~; ~' ~ 5~.5_ !0,675'-700' _ _ -_ ....- -- ~ __ ,_ ...... __, _ ,,,,_ ,,__ /Sg.top 50 ?" liner t9963'-11_798' 326 Bx. ~ _~ tbg. 9902 ?ckrs. t0 ~ !98&9652 :~ co~. ~ Pckr. !0,409 GEOLOGi C FORMA¥IONS Surface . Lowest Tested Name .... _- (11,t35'-65' DST -Wet) pl_ugs_ Re:~.. ];]:~_1_0,~_' . ~_ PRODUCTIVE HORIZONS Depth Contents WELL STATUS Year Jan Feb · Mar Apr. May June July Aug Sept Oct Nov -Dec Fish in hole 99!7'-10,288' (12~" bit,& Grant Remer, 7~;" x 18' 1,bnel D.C. 'z,%;o~" Servco, 7~" x 25' Honel D.C., !2~" ServeD, x 120 D.C., . 7~" ' 12~" Servco, ~ x 90' D.C , ..... ~ 7~." ~ ~O' D.C.: Cm~d .... / i S.O . ~-~ ~ 0917' Drill.ecl .nmt.. tn ..................... OD . ~ack in old hole., fg. 9859' w/150 sx. Dr. out to 9725'. 2g amt. 9883' w/200 sx. St, off Remarks: Re: Hfgh Gas-Q1! Rattos Gran~ te Point . O. ~.1734 .An~ge."-AlUk~. 99501 ~ar S~ir: - _ . kle have your letter of J&nuary 17, lgGg, Indicating that the gas-otl ratios reported for two of your Grant te Potnt wells are tn error. $1'~ce these are not correct, ~111 you please sulxntt & corrected cop~ of the November production report tn order that ~e may correct our flles. Very truly yours.., Homer L. Burre11 Director -%.. MObil Oil Corporation Homer L. Burrell Director Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99503 612 SOUTH FLOWER STREET LOS ANGELES, CALIFORNIA 90054 P. O. Box 1734 Anchorage, Alaska 99503 January 17, 1969 Sir: This is to acknowledge the receipt of your letter dated January 6 1969 0 4 ' znto ~ere reporter these wells during Part of Novem~~~,_NOvember, ~9as having gas-oil --. ~ne ~ .~ ~_._ 68. These we was not subtracted ~a_ ~-~c was bezng injelcl; from the gas when the gas-oil ratios were determined The December, 1968 report will reflect the more ' produced ed recent gauges on these wells which have been adjusted for the injected gas lift gas. At the present time we do not have any wells Producing With a gas- oil ratio exceeding 2000 to 1. The total produced gas reported in No COrrect. HOWever to the u , the gas Vember ~~~rected ;;-~~iocated ~ ~,_ , 1968 for -~ - _ ~uauct' '~~s-oi~ Ji~';~ ........ ~ Lne ~-~ .. ~z o~ Ph We ..... ~-, 1968"~.~ _Y wzsn wA"'~i+~ .......... , ....... ff_.y.,~or due °nvenience. ~ o have You wit~ ~ gas-oil ratios. .... ~ ~sts on any of Our wells at your HHHamilton RECEIVE5 JAN 2 0 1..hq DIVISION OF OiL AND GAS ANCHOrAgE Very t/~71y Founts, .~a SUBMIT IN DUPLIC, --;~-'~TATE OF ALASKA (See othbr';,,- st ructions on OIL AND GAS CONSERVATION COMMITTEE reverse side; i i i _ ii ii i iii [ ! i mi i i WELL COMPLETION OR RECOMPLETION REPORT AND LOG* T -o~' [] EEl 13 .... la. YI'E W ~'.LL: ' '" O11, ~AS ~ ,L WEI,L WELL DRY Other b. TYPE OF COMPLETION: %%' ELL OVER EN BACK RESVR. Other __ NAME OF OPERATOR Mobil Oil Corporation , ADDRESS OF OPERATOR P. O. Box 1734, Anchorage, Alaska ~. LOCATION OF WELL (Report location ciearlff and in =ccordance with any State requirements)* ztsurtac~2383~S & 1368~E from NW Corn. Sec. 13, TION, R12W, s.M. Conductor ~8, Le~ ~3. Granite Point Platform At top prod. interval reporttrd belo~v 3127~S and 646~W from surface location · At total depth 2950'S and ll08'W from surface location or 53'S and 260'E from NW Corner Section 24, TION, R12W, S.M. 5. API NUME~CA~ CODF- 50-133-20046 6. LEA~E DESIGNATION A/qD SERI. A.L. NO. State ADL 18761 7. IF INDIA. N, ALLO~ OR TRIBE NAME 8. UNIT,FArM OR LEASE NAME Union-Mobil State ~1 '9. WELL NO. Granite Point ~11-24 10. FIELD A~D POOL, OR WILDCAT Granite Point-Middle Kenai 11~ SEC', T., R., M., (BOTTOM HOLE 0~./mcrtvE) Sec. 24, TION, R12W, S.M. 12. PEB~IT NO. 67 -57 10-5-67 12-22-67 1-21-68 105' above MLLW (KB) ] 64' above MLLW I~OW MANY* ROTARY TOOLS CABLE TOOL8 11,800MD=il, 068TVD~ [ 11,108MD=10,414TVD~ 3 X 22. PRODUCING INT]~VAL(S), OF THIS COMPLETIOn--TOP, BOTTOM, NAME (MD AND TV'D)* 23. WAS DIRECTIONAL ~ SURVEY MADE Middle Kenai Top = 9836MD; 9172TVD *see attachment for descrip- ] Bottom = 10,700MD; 10,018 T~D tion of individual comple~iqn~ Yes 24. TYPE ELECTRIC AND OTHER LOGS RUN intervals IES, Sonic-Gamma Ray, Dual Induction; CDM, CBL, Gamma Ray -Ne-Iron '" 25. ' ' CASING RECORD (Report all strings set in well) 26. ' " ' LINER KECOH,D ' [ 27. TUBING HECOI~D ' ' "! 326 . ! PERFORATIONS OP~-Aq TO PRODUCTION (Interval. size and number) 9836 - 9866 10,095 - 10,130 10,150 - 10,240 10,315 - 10,350 10,535 - 10,560 10,580 - 10,660 10,675 - 10,700 4-1/2" H/F ' iiii i i i i ii 30. PRODUCTION SCREEN (MD) 25. ACID, SHOT, Fi%A, CTUHE, CE~%lENT SQUEEZE, ETC. Dl~'~f'lI I1N'TI!IRVAL (MD) I AMOUNT. AND KIND O,F. MA'f~E.-'~IA~ USED 3. 1/.2 9902 10~198 & 9682 3, 1/2 ,, .10~.416 10;409 , DATE FIRST PRODUCTION 2/2/68 DaTZ Or TZST. IF. OURS TE~TED [CHOKE SIZE [PROD'N FOR PEI~!OD 2/12/68 12 176/64 FLO%V, TUBING [CA.SLWG PRESSURE [CALCUL~ OIL--BBL. P~mSS. ! ' [~--HOUR R~TE used for fuel and vented I~ODUCTION ME'I'HOD (Flowi~g, gas Iii. t, pumping--size and typo of pump) F 1 owing OIL-BBL. GA.5--MCF, 2086 I I WELL STATUS (Producing or ~,~t-in) Produc lng WA~,,-Bm,. IG~S'OIL ~TIO 1552 ] 3.5 i .744 WATt. BBL. [OIL oP~vrrv-~a~z (CORR.) I, 7] 41.1 ..... tTEST WITNESSED BY Historv, Directional .Survey, ~ore Description. DS% Records, Completion Diagram 33. I hereby certify that the forego, i~ng and attached ./~nfo/mation is complete and-correct as ~letermined from all~vallable records ' - . ........ II III I II I' ~ '~( ;~.~ II . I I I III I II ~ I I I ' *(See Instmcti~s and S~ces tor Additional Data on Reverse Side) t' bii Oil Corporation WELL COHPLETIO'N REPORT ORIGINAL DRI LLING OPERATOR WELL NOo Mobil Oil Corporation Granite Point State 11~24 FIELD Granite Point SEC. 13 STATE LOCATION __, T. ION-, R. 12W S.M. .x~k Alaska COUNTY 2383'S and 1368'E from NW Corner Section 13, TION, R12W, S.M. LAND OFFICE ELEVATIONS 105' (K.B.) ENGINEER LEASE NO. (MAT) GEOLOGIST J. Meyer & H. Hixson 0ATE M~rGh ~, 1968 SIGNED TITLE COMMENCED DRILLING COMPLETED DRILLING TOTAL DEPTH .... 11,800 dUNK 10-5-67 GEOLOGICAL MARKERS DEPTH 12-22-67 PLUGGED OEPTH .... 11.108 ON PRODUCTION 2/2/1968 FLOM'NG/GAS LIFT/PUMPING (CROSS OUT UNNECESSARY MOROS) PRODUCTION DATA ,,, i GRAVITY TOTAL CUT TUBING CASING GAS PRODUCTION, CLEAN OIL CLEAN OIL ~ BEAN SIZE PRESSURE PRESSURE MCF PER DAY , , ~ INITIAL B/D [AFTEr, 10 DAYS 4172 e/O 41.1 .12 to .2 176/64 125 3104 , , CASING RECORD (PRESENT HOLE) · SIZE OF DEPTH TOP WEIGHT .... MEW OR SEAMLESS "GRADE SIZE OF NO.OF SACKS DEPTH OF CEN'.' CASING(A.P. iJ OF SHOE OF CASING OF CASING SECONDHAND OR LAPWELD OF CASING HOLE DRILLED OF CEH. IF THRU PERFS. 18 635 ~40' 70o59 New Seaml. B 22" 800 13 3/8 4030 40" 61 New Seaml. J-55 16" 1900 .9 5/8 10,086 40' 40 to 47 New Seaml'o N80 S95 12 1/4" 515 .......... ~_~.~ 11,798 9963' 29 New Seaml. Pll0 8 1/2 326 PER FOR AT i ON S ................. DISTANCE BET, ' ....... SIZE FROM· TO SiZE OF PERFS. NO.OF ROWS METHOD OF PERFL OF CASING CENTERS , ,, ?_5/8" 9836 10,700 1/2" 4H/F ... _S. chlumberger Hyper Jet ,,, ELECTRIC LOG DEPTHS 635 to 11~800 DR I LLED BY Santa Fe DrillinR Company using_ Rig #71 MOBIL OIL CORPORATION HISTORY OF OIL OR GAS WELL OPERATOR WELL NO. Mobil Oil Corporation Granite Point State 11-24 FIELD Granite Point Sec. 13 T ION R 12W S .M. Signed C.C. Woodruff DATE March 5 ~ 1968 Title Area Engineer Date 196,7 10/5-10/6 DRILLING A MIDDLE KENAI ZONE WELL This well was drilled by Santa Fe Drilling Company using rotary rig #71, positioned over conductor #8 of leg #3 of Mobil Oil's Granite Point Platform. All depths refer to the Kelly Bushin$~ 105' above mean low low water. Drilling 12 1/4" Hole 0'/660'. Opening Hole to 22" 0'/660'; Running Sperry-Sun. Survey: Spudded in w/12 1/4" bit at 3:00 AM 10/5/1967 and drilled to 310'. Opened hole to 22" and ran Sperry Sun Survey 0/275'. Drilled 12 1/4" hole to 660' using Dynadrill for interval 310'/428'. Opened hole to 16" and then to 22" to 660'. 10/6-10/7 Running & Cementin$ 13 3/8" Casing @ 635' ! · Ran 15 joints (637.52') of 18" 70.59# Grade B casing including a Baker guide ! shoe on bottom and simplex collar on top of first joint. Cemented at 635' ,with I 800 sax class "G" Cement with 3% CaC12. · 10/7-10/8. ! D.O.Co I Running Sperry Su.n, Survey to 630'. W.O.C. 24 hours. Drilled out collar at 595' and tested casing to 500 psi. ok. Drilled out shoe at 635' and cleaned out to 660'. Ran Sperry-Sun i Gyroscopic survey 275'/630'. 10/8-10/12! Drilling 12 1/4" Mole 660'/4032'; Runnin~ Schlumberger Electrica1 Logs. Drilled 12 1/4" hole 660'/4032' using a regular drilling set up except for interval 887'/1237' where a Dynadrill was used. ; Rigged· up and ran a Schlumberger IES log 4035'/635' ; · Page 1 MOBIL OIL CORPORATION HISTORY OF OIL OR GAS WELL OPERATOR Mobil Oil Corporation FIELD Granite Point WELL NO. Granite Point State 11-24 Sec. 13 T ION R 12W S.M. ,Signed C.C. Woodruff Date 10/12-10/17 10/17-10/19 DATE March 5~ 1968 Title Area Engineer O en~~!.i!Lf..~_~?~ 16" 635'/4035.'; Running & Cementing 13 3/8" Casing @ 4030'. Ran in with a 16" hole opener and opened hole to 635'/4035'. Conditioned hole to run casing. Ran 97 jts. of 13 3/8" casing. Pipe parted while installing landing hub, and landing joints. Pulled and ran die collar on 11 joints of casing. Landed casing at 4030" and cemented in two stages. First stage pumped 640 sax of Class "G" cement with 3/4% TIC. Opened DV collar and pumped 1260 sax of Class "G" cement. DV tool did not close. D.O.C.; Pressure Testing CasiDg & D.V. Colla.r~ Squeez.in8 D.v. Collar Tagged hard cement at 2271'. Drilled out D.V. tool at 2306'. Pressure tested with 2000 psi, bled off to 1200 psi.' Ran in with 13 3/8" Baker retainer, set prematurely at 1256'. Drilled out retainer and pushed to bottom. Ran a Halliburton RTTS packer and set at 2245' Mixed 100 sax Class "G" cement with 3% CaC12. Squeezed 60 sax in 10 to 15 min. stages for 2 hours. Squeezed 100 sax in stages for 3 hours at a final presssure of 900 psi. Moved retainer to 2185'. Squeezed 115 sax in stages with a final pressure of 2000 psi. Held pressure for one hour. 10/19-10/21 C.O.C.; Pressure Test D.V. Collar~ Changed Mud System To Fresh Water;' Recovering I Iron. i Tagged cement top at 2259'. D.O.C. to 2305' and tested D.V. collar with 2000 psi. [ Pressure 'bled back to 1200 psi. and held C.O. to 4030' and changed to fresh water. I Ran in with 12 1/4" bit and drilled on iron 4032'/38' Ran a Bowen reverse ~ circulat-~ng basket and cored 4038'/40'· 10/21-11/8 1 i Drilling 12 1/4" Hole~ 4040'/9821'. ! Drilled 12 1/4" hole with a regular drilling set-up 4040'/7012~, Ran Speery- ! Sun gyroscopic survey 600'/4000'. i Drilled 12 1/4" hole with regular drilling set-up 7012'/9821' with the · ~ exception of interval 7475'/7494' which was drilled with a Dynadrill. 11/8-11/13 i Corin~ 9821'/9833'; Drilling 12 1/4" Hole .9821'/19~228'. ~ MOBIL OIL CORPORATION HISTORY OF OIL OR GAS WELL OPERATOR WELL NO. DATE Mobil Oil Corporation Granite Point State 11-24 March 5, 1968 FIELD Granite Point Sec. 13 T ION R 12W Signed C. C: Woodruff Title Area Engineer MoM, Date 11/13-11/25 11/25-12/7 Ran an 8 7/16" Christensen diamond corehead and cut 12' of core from 9821'/9833', recovering 11' of oil sand. Drilled 12 1/4" hole 9821'/10,228'. Stuck pipe on bottom.' Fishing For Stuck Pipe; Plugging Back For Redrill Spotted diesel and worked pipe without success. Ran Dialog and found pipe free to 9885'. Backed off at 9885'. Ran 8 5/8" washpipe and washed over fish 9858'/9941'. Screwed into fish .at 9858' and backed off. at 9917' re- covering 2 7-1/4" x 30' drill collars Ran open end drill'pipe at 9917' and cemented plug #1 from 9917'/9700' with 150 sax class "G" cement with 2% CaC12. W.O.C. 24 hours. Ran in and found cement at 9736' D.O C to 9746' · · · · i Ran Dynadrill and drilled 12 1/4" hole 9756'/9806'° Ran a regular drilling '. set-up and drilled 9806'/9866'· Reentered old hole and drilled soft cement i · · Ran open end drill pipe to 9859' and cement with 150 sax Class "G" cement with 15% sand 2% CaC12. W.O.C. 32 hours. D.O.C. 9694'~725'. Ran Dynadrill and drilled 12 1/4" hole 9727'/9883'. Shoulder would not hold. Prepaired to cement plug #3. Ran open end drill pipe to 9862' and cemented with 200 sax Class "G" cement with 15% sand and 3/4% TIC. W.O.C. 24 hours. Tagged cement top at 9654' with 30,000# and 2000 psi pump, cement pumped away slowly. W.~O.C. 9 hours. Cement pumped away slowly with 70,000# and 2300 psi pump. W.O.C. 48 hours. Drilled medium cement 9654'/9664'. W.O.C. 12 hours. Drilled 9664'/9674' at 24'/hoUrs. (Total time W.O.C. 60 hours). Prepaired to run Dynadrill. Total fish left in hole 283'. Sidetracking Original Hole; Drillin~ 12 1/4" Hole 9674'/10~200'. · , Ran ~n w~th Dytladr~ll and drilled 9674"/9678'. Tool stalled due to loss of ~lower bearing. Ran a second Dyndrill and drilled 9678~/9680~ tool stalled ! Reran Dynadrill with a junk sub and dr£11ed 9680~/9689'. Page 3 MOBIL OIL CORPORATION HISTORY OF OIL OR GAS WELL OPERATOR WELL NO. Mobil Oil Corporation FIELD , Granite Point State 11-24 Sec. ,13 Signed Granite Point T ION R · C. C.Woodruff 12W S .M. DATE March 5, 1968 Title Area Engineer Date 12/8-12/9 Ran in with a regular dr~illing set-up with junk sub and drilled 12 1/4" hole 9689'/9768' recovering Dynadrill bearing. Ran 10 5/8" Eastman WhipstocR and sheared pin while setting. Ran a junk basket and recovered 3 pieces of iron. Reran Eastman Whipstock and drilled 8 5/8" rat hole~9774'/9813'. Ran a 12 1/4" bullnose hole opener and opened rat hole 97,95'/9813'. Drilled 12 1/4" hole to 9837'. Ran a 9 7/8" bit on a Dynadrill and drilled 9813'/9938'. Ran a 12 1/4" hole opener and opened 9 7/8" hole to 9938'. Drilled 12 1/4" hole with a regular drilling set-up 9938'/10,200'. Conditioned well for logging. ~ Runnin~ Schlumberser Electric Lo~s 4049'/10~221'. Totals: 243 its 10,088.59' · - - Float Collar @ 10,000' '~ Cemented thrOugh shoe @ 10,086' with 10 bbls seawater followed by 515 sax class "G" cement with 3/4% TIC. Installed OTC casing packing' and tested with 500~) o.k. Page 4 86 jts - 3549.27' - 43o5f~ - ST&C - S95 24 jt$ - 990o13' - 40.~ - ST&C - S95 87 jts - 3591.40' - 40.~ - LT&C - N80; incl. 2 crossovers 43 jts - 1831o72' - 40.~ - Butt., N80 1 jt. - 41.47' - 43.5# - Butt., NS0 1 jr. - 38.73 -~40.~ ~ Butt., LT&C crossovers OTC landing body - 2.00' 1 landing jt 43.87' Ran the following Schlumberger wire line services: IES 10,221'/4049', Dual Induction 10,217'/8500', Sonic-Gamma Ray 10,211'/4049' , and Dipmeter [ 10,180'/4028'. i Conditioned holo ~r,. ~.m casing. 12/9-12/11 i Running. & Cementing 9 5/8" Casing 010~0.86'. i Landed 10~,088' of 9 5/8" casing at 10,086' ~ wit:h details from bott:om to top as follows: MOBIL OIL CORPORATION HISTORY OF OIL OR' GAS WELL OPERATOR WELL NO. DATE Mobil Oil Corpo~' Granite Point State 11-24 March 5~ 1968 FIELD Granite Point Sec. 13 T ION R 12W Signed C. C. Woodruff Title Area Engineer Date 12/11-12/12 12/12-12/23 i 2/23 12/23-12/26 Running Sperry-Sun Gyroscop.ic Survey & Schlumberger CBL Ran a Sperry Sun Survey 4000'/9900'. Drilled out float collar and cement to 10,064'. Ran a cement bond log 10,071-8100'. Found cement top at 9110', bonding poor. D.O.C.; Drilling 8 1/2" Hole~ .10~253'/11~800' Total Depth Ran in with a regular drill set-up and D.O.C. and 'shoe to 10,253'. Drilled 8 1/2" hole, 10,250'/11,800'.. Conditioned hole for logs. Running Schlumberger'Logs 11~810'/11~722'. Ran the following Schlumberger wireline services: IES, Sonic-Gamma Ray, and Dipmeter 11,810'/10,086'. " Running & Cementing 7" Liner at 11~798'~ W.O.C. Landed and cemented 7835' of 7" liner at 11,798' with details from bottom to top as follows: 44 jts - 1834.72' - 2~ - Pll0 - X-Line shoe at tl,798' Landing collar at 11,752' Hanger at 10,001' Receptacle at 9963'~ i Cemented through shoe with 326 sax class "G" cement with 3/4% TIC W 0 C ~ 48 hours. 12/26-'12/29 { Pressure Testing Lap; Squeezing Lap; W.O.Co'I D.O.C. A , I Ran into top of liner at 9963', no cement. Pressure tested lap to 300~ o.K. ; Ran a Hilliburton RTTS tool and set at 9941'· Tested lap to 5000 psi, did not ~ hold· Set a Howco 9 5/8" D.M. retainer at 9929'· Pumped 58 cu.ft. Class "G" ~ cement followed by 10 cu.ft water and 892 cu.ft, of mud Squeezed 90 cuft ~ @ 5000 psi, squeezing 30 cu.ft, cemen~ around lap. W.O.C. 24 hours. , Ran to retainer at 9929' and drilled hard cement 9931'/9963'. MOBIL OIL CORPORATION HISTORY OF OIL OR GAS WELL OPERATOR WELL NO. DATE Mobil Oil Corporation Granite Point State 11-24 March 5, 1968 FIELD Granite Point Sec. 13 T ION R 12W Signed C. C'. Woodruff Title Area Engineer S ,M. .. Date 12/29-12/30 12/30-12/31 12/31-1/7 Running Schlumberger CBL & Gamma Ray-Neutron Log; Perforatin~ 11~ 135'/11~ 165'. Ran a Sperry-Sun Gyroscopic survey, tool failed. Ran a Cement Bond Log 11,748'/9000' and Gamma Ray-Neutron Log 11,768'/9500'. Displaced mud with saltwater. Ran a Schlumberger jet gun and perforated 4 1/2" hole/foot 11,135'/11,165'. Running DST #1 11,135'/11,165'; Running Sperry-Sun Survey Ran a Howco drill stem tester, packer set at 11 060' tail to .11,075' I.F. = 5 min~ t.S.I. = 1 hr; F.F. = 2hrs, F.S.I. = 4 hrs. Recovered 43 bbl waters Ran a Sperry-Sun gyroscopic survey 11,700'/9900'. Shooting., Pressure Testing & S~ueezing for W.S.O. Ran Howco CI cement retainer, stopped at 9966'. Retainer accidentaly set. Drilled out retainer. Ran retainer #2 to 11,120'. Pressured to 5000 psi, tool failed. Ran retainer #3 to 11,108'. Pressured to 5100 psi, with no leaks° Ran a Schlumberger jet gun and perforated 4 1/2" holes at 10,750'. Ran Howco RTTS tool and set at 10,703'. Tested holes at 10,750' with 5000 psi o.k. Pulled tool to 10,100'. Ran a Schlumberger thru tubing gun and perforated 4 holes at 10,400'. Tested with 5000 psi o.k. Ran a Schlumberger 4" gun and shot 4 1/2" holes at 9950'. Ran a Howco RTTS tool and set at 9843'. Tested holes at 9950' with 5000 psi· O.K. Pulled tool to 9285'. Ran a Schlumberger thru tubing gun and shot 4 1/2" holes at 9765'. Tested with 5000 psi, and had a feed rate of 2 cu.ft./min, at 5000 psi, held at 4250 psi· Ran a Howco bridgeplug, set at 9867' and tested to 5000 psi, O.K. Ran a Howco magnesium retainer and set at 9715'· Tool failed at 5500 psi. Pulled ~ and ran a second'retainer set at 9702'· Pumped 4 cu.ft./min through perforations at 9765' with 4000 psi. Set Howco RTTS tool at 9692' and broke down~perfs, at I 9765' with 5500 Psi. ~Pumped 30 cu.ft. Water, 30 cu·ft, cement at 11~, 30 cu.ft. i water, and 880 c~.ft, salt water. Squeezed 100 cu.ft, at 5500 pressure bled to MOBIL OIL CORPORATION HISTORY OF OIL OR GAS WELL OPERATOR WELL NO. Mobil Oil Corporation Granite Point State 11-24 FIELD Granite Point Sec. 13 T ION R 12W S.M. Signed C.C.' Woodruff DATE March 5, 1968 Title Area Engineer Date 1/7-1/lO 1/11 3500~/. Squeezed 6 cu, ft. by stages, pressure bled to 2750 psi° Cleared holes with 26 cu. ft. water. Squeeze #2, interval 9765', pumped 30 cu.ft, water, 30 cu.ft, cement at 110-112#, 30 cu.ft.%ater and 886 cu.ft, saltwater. Squeezed total of 24 cu.ft. Squeeze #3, interval 9765'. Pulled RTTS tool. Drilled out retainers at 9702' and 9715'. Set retainer at 9661'. Broke down perfs, at 9765' 3 cu.ft./min at 5500 psi° Pumped 30 cuoft, water, 47 cu.ft, cement at 110-114#, 30 cu.ft, water, 856 cu.ft, salt water. Squeezed 94 cu.ft. displacing 15 cu.ft, cement through perfs, at 5750 psi. Pressure bled to 4900 psi. D.O.C.~ Perforate for Production 10~700/9836' Drilled out retainer at 9661'. Drilled hard cement 9724' to 9867'. Ran a RTTS tool and set at 9745'. Tested perfs, at 9765' with 5000 psi O.K. C.O. hole to 11,108'. Ran Schlumberger Hyper-Jet perforating guns and shot 4 holes/foot in the following intervals: 10,700 - 10,675 = 25' 10,660 - 10,580 = 80' 10,560 - 10,535 - 25' 10,350 - 10,315 = 35' 10,.240 - 10,150 = 90' 10,130 - 10,095 - 35' 9866 - 9836 = 30' I Running Tubing and Completing for Production i Ran aiong string of 3 1/2" tubing to 10,177 and tested with 5000 psi. Ran ~ a short string of 3 1/2" tubing and tied into packer at 9400'. Ran 300' as dual string. Tested short string, would not hold 5000 psi. Pulled 300' dual istring and short string. Found leaks in tubing collars. Reran short string : testing every 10 stands with 5000 psi. Ran 300' dual string and tested with ~ 5000 psi O.K. MOBIL OIL CORPORATION HISTORY OF OIL OR GAS WELL OPERATOR Mobil Oil Corporation FIELD Granite Point WELL NO. Granite Point State 11-24 Sec. 13 T ION R 12W S.M. S igne d C. C. Woodruff DATE March 5, 1968 Title Area Engineer Date Attempted to pull Otis plug from X-nipple, no success. Pulled both strings of tubing to 300'. Pulled short string and found plug locked in X-nipple with fine sand. Reran tubing and tested to 5000 psi. OoK. Checked mandrels with shifting tool, tools parted. Fished out jars and tools, retreiw~_~ plug. Installed flow lines. Rig released and well completed for production 12:00AM 1/21/1968 -8- CORE DESCRIPTION Company: Mobil Oil Corporation Well: Granite Point State #11-24 Described: H. C. Hixson Date: 11-9-1967 Zone cored: A-Zone Middle Kenai Sand Interval cored: 9821' to 9833'; 12' cut, 11' recovered Rate per Foot: 9821 - 22 = 26M/F 22 - 23 = 30M/F 23 - 24 = 8 M/F 9824-25=15M/F 25-26=14M/F 26-27=14M/F 9827-28=15M/F 28-29= 8M/F 29-30=24M/F 9830-31=30M/F 31-32=20M/F 32-33= 8M/F GENERAL DESCRIPTION Sandstone; light tanish gray, light tan even staining; medium grained to conglomeritic, pebbles 1/4" to 3/4i' diam.; angular to subangular grains with rounded to sub rounded pebbles; fair porosity, fair to poor permeability; fair to poorly sorted; hard; 60% quartz, 35% feldspar and lithic fragments, - approx. 10% of lithic component is a black carbonaceous siltstone; 5% matrix - clay, v/slightly calcareous, silidous cementing; Kerosine odor, bright canary yellow fluorescence; v/light tan cut, blue whi'te cut fluorescence 9821 Pebbly sandstone - pebbles 1" diam. , 9822 9823 9824 9825 9826 Pebbly '.Zone - apparent dip angle 20°+ Pebbly sandstone 9827 sandstone - fine to medium w/thin laminations of silt and v/fine sand some indication of cross bedding sandstone grading into conglomerate 9828 9829 9830 9831 9832 conglomerate - pebbles 1/4" to 1" diameter sandstone - medium grained w/ occasional pebbles. FORMATION TEST REPORT OPERATOR: Mobil Oil~Cor~. · \ LOCATION: Granite Poznt Field COUNTY: STATE: Well: 11-24 Test No.: 1 SEC: Alaska 14 T: ION R: 12W ELEV: 105KB WITNESSED BY: H. Hixson TEST COMPANY: Halliburton TICKET NO: CHARTS ORDERED: DATE: 12-30-1967 TEST INTERVAL: 11,135 11,165 FORMATION: CASING: Middle Kenai TOTAL DEPTH: , l10~8Q,0 ,TD~ 11~,752 PBTD .. I.D. O.D. WEIGHT .INTERVAL CAPACITY : BBL/FT FT/BBL 8.75 9 5/8" 40 - 43 0 - 10,086 .0745 13.43 6.18 7" 29 9963 - TD '..0372 26.88 DRILL PIPE 2.76 or 4.27 TUB ING: 3 1/2" 13.30 1706 .0074 134.75 5" 19,,. ~0 9,335 , ,,017~,, , 56.30 CUSHION TYPE: BBLS: CHOKE SIZE: BOTTOM: 5/8 TOP: 1/2 and 3/4 MUD CHARACTERISTICS: WEIGHT: 74 VI.SCOS ITY: GPG: WATER LOSS: TYPE: · TEMP: Rm: Saltwater TIME BREAKDOWN OF TEST: 1st Flow From 11:50 To 11:55 m£n. 5' I.S,I. From, 11:55 To . 12:55 min. 60' ,, 2nd Flow From 1'2:55 To 2:55 ,',lin. 120' .. F.S, I. . From 2:~5 To 6:55 _ min. 240' Mud Pit Measurements Tank measurement - 2.83 bbl/inch Total Capacity of DP ' 1706' 3 1/2 DP x .0074 = 12.62 bbl = 4.46" 9335' 5" DP x .0178 = 166.16 bbl= 60" Page 1 Total Pit Displacement=64.5" Pit Measurements during Reversal Start - 19 1/2" Fluid to Surface = 68" Recovered fluid - 64,5 - 4~.5 ~- i6" x 2.83 bbl/inch --45.28 bbl. DIAGRAM OF TEST TOOL: CALCULATIONS: ANNULAR VOLUME 60' X .0372 Rat Hole Internal Below Tail Pipe X Capacity in bbl/ft 2.2320 = bbls of mud , , FI X.. .0396 Internal Base of Tail Pipe to Packer X Capacity between Rat .Hole & Tail Pipe 0.2772 bbls of mud Total Annular Volume FILL UP IN TOOLS BELOW BY-PASS VALVE -- ANNULAR MUD 2.5092 bbls of mud Interval--Bottom Tail Pipe to By-Pass Valve X Capaci'ty in bbl/ft bbls of mud Page 2 .' FILL UP IN DRILL PIPE OR TOOLS ABOVE BY-PASS VALVE--CUSHION bbls. Cushion X Capacity of Tools in ft/bbl TOTAL BBLS. ANNULAR MUD & CUSHION feet of rise + + Annular Vol. + Mud Fillup, in Tools + bbls. Cushion , TOTAL RISE ANNULAR MUD & CUSHION 2.51 Total bbls. Interval,Base Tail Pipe to By-Pass Valve + Rise of Cushion Total Rise HYDROSTATIC MUD PRESSURE (From Engineer's Tables: For given weight mud--~number Ibs/sq.in./100' depth) Total Hydrostatic Measured on Bottom Recorder: 11,071 X 51.90 ~epth of Well to Bottom Recorder X lbs/sq.in../100' depth 5745.8 psi 1ST FLOW: ANNULUS MUD LEVEL: · STEADY: x DROPPED: IF DROPPED, HOW MUCH? VOL. USED TO REFILL: FLUID TO SURFACE ( mins) AIR x CUSHION GAS MUD OIL WATER GAUGE METHOD (GAUGE PRESSURE + CONSTANT x COEFFICIENT = MCF/DAY) ~31Ow' in' iib'/sq'.i~'.' ' mi~{'. ~ Diameter Choke ..... G.ahge, ,, Const. Coeff. '"Rate 3,u,cket . . · ..... Fl,ow, P.ipe Size Pressure Full Bkt 1 1/4" 5/8+1/i Good~Blo~ Page 3 GE~ERAL RE~A~,~S: Blow started weak and built very rapidly to a good blow displacing a full bucket of water (12" hydrostatic) 2nd FLOW: FLUID TO SURFACE: (, min.) AIR CUSHION GAS MUD OIL WATER Blow in ['~'b'/sq.in. mi'n. Di'aL'e~t'er Choke Gauge" const. ' c0'eff/ Rate Bucket t Flow Pipe Size Pressure . 5/8 Full 1 1/2 1/4 Full Buck(t medium to strong building ...... ................ .,, Full ..... 5 1./.4 .... .1/..4 . Med,ium.to strgng ........ Full - . ..... 15 .......... Blow remaining st~'on~ and, ,co~ns. tant , ,, · Pressur ~- 5 lbs.+ I · .i Full 40 . Good stro,ng const~Lnt blow .... 1 hr 2,) min. Blow nearly dead opened 3 /4" choke to ........ produ,ct LOn room, hl.dj good,,., b.low then. i ....... well died - v/wea): blow with only but~ble hose open. GENERAL REMARKS: Page 4 RE COVE RY: First samples w, "~ black oily saltwater - no gas detected - samples changed to dark' brown mud emulsion then golden brown to yellow foamy saltwater then gray muddy saltwater. Calculated from mud pit displacement = 45.28 - 2.51 Rot. Hole = 42.77 bbl. fluid of this 5%+ was oil the rest saltwater. 'SAMPLES COLLECTED: see attachment PRESSURES RECORDED: Element Range ]lock Range 24 24 24 Fype Ser. No. i 2857 2855 2847 3epth 11050 ! 11067 11071 . Blanked off Inside ' Outside Outside ~ ~ IFP 99 102 105 ~ ~ FFP 'i124 148 132 IHP 5286 5223 5258 o ISIP 4918 4718 4945 FFP 559 511 ,~3 ~ FSIP. ,,. 4845 48,31 .,. 4840, FHP 5286 5223 5258 TEST INTERVAL TEMP.: 166° Page 5 SA~IPLES COLLECTED S amp 1 e 1 2 3 4 5 6 7 8 9 10 11 ppm C1- x 1.65 118,000 126,000 122,000 126,000 130,000 160,000 140,000 138,000 95,000 48,000 22,000 ppm NaC 1 194,700 207,900 201,300 207,900 214,500 264,000 231,000 227,700 156,750 79,200 36,300 = 0.2 R @ 70° Page 6 Ticket I~ ~n. 2nd Min. ~ ~ Kind Hallibu.on ~.,j 60,, , 2~0,,. of Job ~oo~ ~a~ Di~rict ~c~o~a~e Office ~ R~d~n~s ~rr~d T~r G G Damron Wi~e,, A. MacNeili , ,, , , , Top ~,~e i1050 Ft. no ~f Con~ct~ S~TA FE DRILLING CO~Y SM , , ~T. H~r Top P.R.D. No. 2857 24 ~ .~°fi~ .105.9~ ~ Packer 11~060' Initial Hy~ro Total Boffom Mud P~s~re 5286 5245 ~th !1 ~ 800 ~ Packer lnitiaICIo~ In~al Net Pay 30v in Pres. 4918 4929 Test~ 11~060-11752" Tested Ke~ai I.ifi=i 99 ~ 114 C=si.~ o, FlowPms. 198 Z .188 Helena 9 5/8" Csg. 7" Pe~. ~8o~. 11,165" ,,, ' Fi.=! 124 ~ 129 Surface 1 in ~.om Flow P~ 559 ~ 540 Choke 1/2" Choke 5/8" Final ~los~ Siz~ ~ ~i.d 5" 3~" Drill ~oll.r~ i. Pr.s.' 4845 4845 Drill Pi~ & IF Fin.i Hyd~ M.d (cu- ft.) Mud P~s~ 5286 , 5245 Weight 74 pelt water Dep~ Blanked Tem~rature .F bt. Anchor Size ID 2" C... ~... 11067 ~. Mas ~ 166 .~ ~.~ , BT. "~ Da~hs D~t~ of D C I P ..R.D. No. , 2855 24 ~ . M... F,om Kelly, bu~,hin~ T.s~.r Val~. 11;040 l.~i~l My~m ~" ~ou.~ Da~ Back M.d P~. 52~3 5231 C.shio. - ~. pr~. · in P~. 4918 4916 Reco~er~ 43 bbls F~ .f oil cut salt water I.i~i~l 102 ~ 128 Flow P~ 179 Z 189 ~.~ F~ .f ' Flow Pr~. 511 ~ 535 . R~v~ F~ ~ inP~. ~8~ ~7- ~~oYe~ Feet of Final Hydro Oil ~ater Mud P~s. 5223 5231 . A.P.I. Gmvi~ Oep~ Blanked Gas Su~ace Got.~uga ~07~ Ft. ~ ~ Gravi~ Pre~sure ~. H~r Tool ~"~0 ~7 ~ Tool A.~. P.K.D. No. ~8~7 ~ ~l~k Opened ~:50 ~ P.~ ~lo~d ~:55 ~ Initial Hydro Initial Cloud in Pres. 4945 4940 ute first flow. . Closed for a 60 m~nute initial initial 105 i 147 Flow P~,. 210 . 2 211 closed in pressure, To°l r~-opened with a weak ~ ...... 132 I 139 : . ~.~.-~.~. 553 ~- 2 553 blow throughout ~est, . ~.~ ......... ~ , Closed tool and r ersed ~inP~s. 4840 4854 out test at 2:55 PM Pulled loose at 6:55 Final Hydro ..~u4 Pros, 5258 5250 formatiON. TEST DATA SPECIAL PRESSURE DATA Gauge No. )o First Flow Period Time Dell. .000' .000 .020 PSIG Temp. Corr. 114 129 Depth 11050~ Initial Closed In' Pressure Time Dell. .000 .0192 .0384 .0576 ·0768 .0960 .1152 .1344 .1536 · 1728 .1920 t+e P$1G Temp. Corr. 129 2574 4017 C|ock 24 hour Second Flow Period Time Deft. .000 188 .0513 260 .1026 4451 ,1539 4621 4724 4791 4840 4879 4906 4929 .2565 .3078 ·3591 .4104 PSIG Temp. Corr. 314 354 389 438 463 5OO 540 Ticket No. 318599 Final Closed In Pressure Time Deft. .000" .000 .O8O3 t + e PSIG Log, Temp. 0 Corr. 540 3528 .1606 417,5 .2409 4409 .3212 4542 .4015 4631 .'4818 4700 .5621 4746 ,6424 ,7227 .8030 4786 4815 4845 Gauge No. , )o .000 .020 )I0 leading InterYal 2855 ~ 128 125 Depth 11067" Clock 24 hour · 000 125 .000 189 .000 53.5 .0191 2486 4O48 · 0.511 · 1022 261 312 .0815. · 16.30 3506 4.1'71 .U575 ' 443g .1533 350 .2445 4406 .0764 4599 .2044 386 ,3260 454.1 ,0955 4704 .2555 422 ,407.5 4628 .1146 4773 .3066 460 .4890 4691 .1337 4824 4865 4890 4916 .1528 .5705 .6520 · 7 3 3 r5 .81.50 Z4 .1719 o 1910 .3577 496 ,4088 535 15 474.0 4811 Minutes I:EMARKS: SPECIAL PRESSURE .DATA Gauge No. First Flow Period PSIG Temp. Corr. Time Deft. Time Deft. .000" Initial Closed in' Pressure 147 .000 139 ·0197 .0394 11071~ PSIG Temp. Corr. Clock 24 hour Second Flow Period Time Deft. PSIG Temp. tort, 139 .000 211 2016 .0516 276 ·1032 .000 .020 3916 332 ,, , I Ticket ,,, No,. , 3!859~ Final Closed In Pressure Time Deft. t -I- {} P$1G .000" Log~ Temp. Corr. .000 553 · 0821 3551 · 1642 4,193 .0591 4418 .1548 368 .2463 4426 .0788 4608 . 2064 408 . 3284 4559 4718 4794 4846 4885 4916 .0985 ·1182 .1379 · 2580 .3096 .3612 .4128 .1576 .1773 442 ·4105 4648 482 .4926 4.713 518 ,.5747 4,757 553 .6568 4796 · 7389 4828 .1970 4940 .8210 4.854 Gauge No. b PI0 eading Interval EMARK$: Depth Clock hour 15 , . I[ 24 ARinutes SPECIAL PRESSURE DATA , 5 MR. FIELD NAME SIZE CASING cOmPANY TELEPHONE DATE -' ......... WEIGHT GRADE THREAD DEPTH SIZE WEIGHT GRADE THREAD DEPTH O SAFETY EQUIPMENT O COMPLETION EQUIPMENT O POST COMPLETION EQUIPMENT TUBING T LT THREAD1 1,~ ! !/' ~7 ~:~. ,4,.,,~ . ~.~I 3 ~" :i~4~7 ~/y~. 71 ~¢,,'I,,~ ~ ~r~ .?,,..t :'7' .j'Z (~Y~AS LIFT EQUIPMENT' (~I:~ACKERS AND ACCESSORIES S~TIMATE /4 3 71Z, 3'3 ? ......................... :'--:-'-: "-': ""~ "'"i ........... ~'"' :'--"! -' : ............................... : ......... ~...;........~...!......~....:__ f .......................... :'"'"'"':-'-~ ................ ~-" ?'"'": F " !' ::::_.:::: :'.::"-::_ :.,. :-.L ::':' i. i __..': ~i :. 'i !..'.'L::i :.'.":i ':!'::::'?:': Z:':"_:Z : : : ........... :'i" ':-:T-'T-': '"'"'""-': ...... ii-:!' ':':-: i: . : ................. ; ..................... :- T" -:-'T "':'""T'--:---; ....... m ~' - i"-' ~''' -: .......... ! .... ~ ..... . ....................... T"' .7 ~-.-~- :.- L._.:_ ~ ...:.... L ........... ~ .................. t-' r- ~ ....... -":" ?""?'-'"i i"' ................................ :":- :' !'-: ...... : .................. :. ..... :, ........................................... ....... . . . /.~ , 23~.qZ {, 7.>- TOTAL ESTIMATE COMPLETION PROCEDURE .22. PREPARED BY WELL NAME ~I,,I~. OFFICE ] /.;,.,,.,,' FIELD NAME I~ ........ ./_ /2 TELEPHONE DATE ........................... _ .............................. ;_cz;: ...... t ...... ?:.._::::!t:. . :'::':. -:.- ..':-;:-':-- _ '?':". ............. t PREPARED FOR COMPANY TELEPHONE DATE MR. 1,.-'%..~) '' / ' '/! ' . FIELD NAME WELL NAME CEXUNTY STATE [~] NEW ..... SIZE WEIGHT GRADE THREAD DEPTH SIZE WEIGHT GRADE THREAD DEPTH I 0 SAFETY EQUIPMENT OGAS LIFT EQUIPMENT 0 COMPLETION EQUIPMENT OPA~KERS AND ACCESSORIES 0 POST COMPLETION EQUIPMENT DESCRIPTION OF EQUIPMENT AND SERVICES Z..-...../.; .... ~ · . . . ._ , ~ . , .;.~ 1 ? -..)-L ,1,.,,~, ,:. c,, / ?. "', -1,_,/,. · . ,. t/.,' ./,' · :",.,e ,t~ ' ,~ -,,', ~,' c. '.C..-~ / ? ->. /., "' .L'-/Y ~'~ c.'/,~ y~:.,,., c'x ~,-.~.-::.,,-,5.,-/ " ': ,/ ~'- / 5~ '.~ ,,/:..;;,:? . r' / :4 ' /% '/,h'~- , ~ :X_/t ," ,"," ~: .:,;,: /,., , . ,., . ~ . TOTAL: '7 ?, z/? ESTIMATE ESTIMATE ;3 . t/, · "', 4'.'" .~ 7.." .;,/7 COMPLETION PROCEDURE PREPARED BY OFFICE ";:-.. '"'-- ,; '. 'U~; 'L,, J ~ .... ,,'t WEL~'"' NAM E FIELD NAME /' --, -,' ,;7..:-:-/ I ' .I '; / . t ' . .... ' ., ,., ,.' ~ TELEPHONE DATE t ' MR. FIELD NAME WELL NAME ¢%~, ?~ ,~ 7 .~/. /~ />2 7' SIZE WEIGHT GRADe COMPANY TLiLEPHONE DATE I-:' ';' :-/:~,.,,, I ~ COUNTY STATE ~E]- NEW ' i WORKOVER THREAD DEPTH ' SIZE WEIGHT GRADE THREAD DEPTH O SAFETY EQUIPMENT ~)-GAS'T. IFT EQUIPMENT OCOMPLETION EQUIPMENT O POST COMPLETION EQUIPMENT SIZE Ut MT LT DESCRIPTION OF EQUIPMENT AND SERVICES THREAD COMPLETION PROCEDURE (~)~CKERS AND ACCESSORIES TOTAL ESTIMATE ,.,TIMATE PREPARED BY t ¥/, c o OFFICE ,/./,, .~ FIELD NAME I::.:. ...... '7: ..,..-?.' ~ TELEPHONE J~ ~'"'.7-- DATE PREPARED FOR ' TUBING UT I LT ................ · ...................... SIZE [MT THREAD[ NAME c.,-,~.,,/~ ,4>.;.,~ SIZE WEIGHT COMPANY TELEPHONE DATE / WELL NAME NEW GRADE THREAD DEPTH THREAD DEPTH 1 ~'X~'~ERS AND ACCESSOR4ES POST COMPLETION EQUIPMENT SIZE WEIGHT . GRADE 0 SAFETY EQUIPMENT (~As LIFT EQUIPMENT O COMPLETION EQUIPMENT DESCRIPTION OF EQUIPMENT AND SERVICES ,$'3 - - J~"' -' ' I' { ~." .~ / ..J ¢. .4,.,,.,,.,, _q,,, I ..~.~ '/,/,.,,., i-._ ~ :-, ,: -- , ' - ~ z I . .',_ ,'.- .,,,%- .~'" ~ '- .: 5',, . I,:, ,._)% 4 '~ /4,-me'~ ,.5.,~1 Vw~,.~ 0~ S: ? z~/, r, :/,,,... c x ,,,,-:,,~.,...~,-,. / ¢ / ~~ '. ,~rr,, rc 6,,,,, l 3; ,~_ Y,.,,~,., c i ~$~b. - ....~ _ ¢ ' / ,, ' '/ -%$ ~ .O,.~-,', ~,.,,,~. r->: ,,.,,~,~.7,.,.1 ! .2..:,g. ¢. A,-,,.. ,. ,~ .-,.,I 3 ;~ /,.,,,.,.,,. 3- ? n , ~, ~, s '/v ,,,,.. · c-z ,,....~,~,.,j,.,.. / ¢ ,~m ,.,,¢ 4/.,4,-.,..,:. ~,,l 3~,,' /..7,,,;. s-,, *.~ ~,/,, L? c.v ,,,~.,~I'~ i ..7 ~ ,.~.~. ,4-.,,,,,: -..s"~,~t ,.7, :: ,' ' - i ,t: . "?,_.b,,.-. -., ~ g' 0¢, A,-,,,~:'- 5..,/ .~ ~'5 " /,.5 /, .-. '., S-/,/ 0 1,'~ ¢,,,. (x ~,..,,..,.,/,.,,I ! A,.,,~-,:~ :.., / .3 .'.z" z..,, '/ / i''," .;' j,,,..t,;,. }~ .; = ,,, ;, : .__ ~ ,' ,~o,~- - - - · ,~, . TOTAL ESTIMATE COMPLETION PROCEDURe ESTIMATE 7¢.c3. x3 ~73£. 2 3 72, z/?,/ 7, /o -- PREPARED SY WELL N.~ME $~/~ I/-~,/. OFFICE /f:,,..,?~ ,' ,,,/.,:~ ;.. F:IELD NAME f.,~,,~,,.,r ~, I:....,'i..,q..:,/ TELEPHONE ].2,~ z-""/,'~ .. ' 'I', DATE Ct.t, ,? INDIVIDUAL COMPLETION INTERVALS t~At~ Zone Top: 9836'MD; 9172'TVD; 3127'S & 646'W from surface location Bottom: 9868'MD; 9205'TVD; 3126'S & 652'W from surface location t'Btt Zone Top: 10,093'MD; 9424'TVD; 3119'S & 697'W from surface location Bottom: 10,350'MD; 9678'TVD; 3108'S & 768'W from surface location "C" Zone Top: 10,535'MD; 9834'TVD; 3099'S & 784'W from surface location Bottom: 10,700'MD; 10,018'TVD; 3089'S & 817'W from surface location 3/5/1968' DIRECTIONAL SURVEY REPORT FOR MOBIL OIL COMPANY TYPE OF SURVEY: Oryoscopic Multishot SURVEY DEPTH: FROM. I 275 .......... ~, TO 630 ~FT. LEASE' Granite Point State ,WELL NO. 11-24 FIELD: . Granite Point Kenai Penn. Borough COUNTY/PARISH .STATE Alaska DATE OF SURVEY 10-8-67 NO., SU-3-1b163 OFFICE: Anchorage, Alaska ..................... T--'~'I~':~'"'~[P ] ~[~TIC. AL D[P?H ANGL[ DIRECTION OF INCLINATION MEASURED COURSE DISPLACEMENT TOTAL DISPLACEMENT CO~[;C T~O ~ _ O~PT~_~ O~ COURSE ,. ..i i.. .... , ~o ,. ~;~ ~,a~ ~.~.~ i~o~' 32-48 400 ~¢.q4. :4~q,~4 G°~' ~ 7/. ~ S 7~ ~ ~ ,43 ~ /, 7~ /, 57 7,2~ ~4-oo 4~ 14,~/ 4~,75 3°4~' ~. Go ~ ~ ~ ~S ~ .~ ,g~/ /.g~ ~.+5 %// ,~7'20 ~ ' ~5-20 ~0 '24.~q .5¢q,zO S=2o' ,, ~ S~ W ~. &O ~5 I,l& 2,oi ~,~? 1%/0 .~I-40 2.5 [,o0 ~4,~ S~?g, 59 T=~' ~ , '. , ' ,, ....... ........ - ! ....... . ~ ' ., ............. ' ~ .... . ...... , .... . .. ~ ". ..... ,.. ............. ...... ....... ..... ......... , ~ , .......... ,, . ~ ' , . ., .. DONE BY: ~ ,. , . ,. , ...... CK. ~Y: ,_ · , .............. , ,. , INDIVIDUAL COMPLETION INTERVALS ,,A,, Zone Top: 9836'MD; 9172'TVD; 3127'S & 646'W from surface location Bottom: 9868'MD; 9205'TVD; 3126'S & 652'W from surface location "B" Zone Top: 10,093'MD; 9424'TVD; 3119'S & 697'W from surface location Bottom: 10,350'MD; 9678'TVD; 3108'S & 768'W from surf.ace location "Ct' Zone Top: 10,535'MD; 9834'TVD; 3099'S & 784'W from surface location Bottom: 10,700'MD; 10, 018 'TVD; 3089'S & 817'W from surface location 3/5/1968 DIRECTIONAL SURVEY REPORT FOR MOBIL 0IL COMPANY TYPE OF SURVEY: Gryoscopic Multishot SURVEY SZPTH: FROM O . FT..TO · 275 LEASE: Granite Point State WELL NO. FIELD: Granite Point COUNTY/PARISH Kenai Penno Borough DATE OF SURVEY 10-~-67, JOB NO., Anchorage, Alask~ OFFICE: Alaska , STATE SU-3-16161 N · ". :..)7"/':; ~'---,,,L---~ --~--.'"~' "~ JOB NO. ~/I - ~- / ~ / & / J SURVEY FIELD ~ ~]1 ~-~ ~/~ ~ S DATE __ / ~ -- ~- ~ 7 DEPTH VERTICAL DEPTH ANGLE DIRECTION OF INCLINATION MEASURED COURSE DISPLACEMENT TOTAL DISPLACEMENT CORRECTED OF COURSE TIME INCliN- DEV. ~ TOTAL COURSE TOTAL aTION OBSERVED CORR. CORRECTED NORTH SOUTH EAST WEST NORTH SOUTH EAST WEST ............... ~l Il ~ ..... .,~ /~'~ /~ IoO. oo i~o.oo /~' ~ ~/. ~ /~ ~ ~ ~ ,~ ~ .~3 ,Z~ " . ¢ ' , ...... . . .......... . ..... ................... ..... .......... ....................... , .......................... ...... . ...... .................. ........ .... .... ~,, .. · ..... ...... ' . ........ DON E BY: .......... ~ ..... ~K. BY: DIRECTIONAL SURVEY REPORT FOR MOBIL OIL, CORPORATtO~ ........ TYPE OF SURVEY:, GYROSCOPIC MULTISHOT SURVEY DEPTH: FROM LEASE:.. ,STATE ?~,.00, ..... FT. TO FIELD:. GRANITE POINT WELL .0. ~ COUNTY/PARISH ..KENAI ..PEN, BOR,. DATE OF SURVEY 12/30~67 .. OFFICE: ANCHORAGE, ALASK/~ ... , , STATF AI.ASK'A JoB NO.~ s[~-3-]6?n7 . w~.. ,o.. ~'-rAq-F_ !J 2 ~ w - . ~o, ,o. S FIELD ~"') I--~'E ., _ law $ DATE MEASUREO DEPTH VERTICAL DEPTH ANGLE DIRECTION OF INCLINATION MEASURED COURSE DISPLACEMENT TOTAL DISPLACEMENT CORRECTED OF COURSE , , INCLIN- DEV. TIME CCXJR~ETOTAL COURSE TOTAL ATION OBSERVED CORR. CORRECTED NORTH SOUTH EAST WEST NORTH SOUTH EAST WEST ........ , ,. ............ __ .... ( q~oo ':?a~,,,8~ 7-4, ~/.),:';¢.,¢ ~,. ~ o--.x- /.,'o lDo lO, DOCq],qq q3S:~,,8'/ 1172 Al , . ...... · ~. , . ~-, ,,. '-~ ,, , · '' /o,,-,~z: .?~,...,.,¢ 9?~g.Eq t/~/ It/ · . · , '.. '9 ..:__ '- ' !O.,xoc q7,72 ¢~zg.~ /2V4 /xl '~¢ IA/ ,.~q,.~ 2d. qo .~lol,~,.. . *'7'-?;:'-';'-., ..,,.._ ,. ~ . p z>p d a~ ??'-,'..: .:. /O,,'.oot::.. 7/,2,.. qo/£O, Og 22 .~; !~ ? ~ W ~ St 2..O,~d '"' ......... / Io."?oc9'/':/h /¢,0/7.¢3 il Z14 f hJ ?2 .W.~.,?..9 } I tg,J? ~"o¢~','°' ~"'~" -. I /o. ¢,oo ~?.72_ /o//s:.~o:~ 12 F4 k/ · tooIo, c/os.~7,,¢5 ID2/.:¢,/'8 12-..5/.'I. ltl ,,~ ...r- -2. L,,,.Od. . . . . l/,?.OOj C:,,).5,. fl. 1o(Yo1,.4,,5. . ./~..-. A/ ¢(.p ~ 1~,~"7. 2..2,23. .:-:0.p,.",/,'7~ ¢~.0,. ..... q'7,: ~l,gOO9..,'.h~.g /Ds~(,:,,~.'~ IS V2 AI ~ \ /~,uoo9"g,-,:_s" /~{oqO.':;: /ct"' .. t',4 ~" I!,L,",o¢ 9z!,,.s.¢ /,~gTq. q./ .lq ' ' .... /"4 (o,.:~ t^1/z/, ~'8, 2.fl'.O I ?¢ <'.* .os.. . .. .-. . fo~'i:',"',~..',. ,,oo/~,?¢._,-., e,¢.,¢z /o?.-/,./:,0~' '/¢;,',> ...... ,',,/ 57 /I, 755 5),fl3!/o2..,,qe, Iq ?,4 IV G ~,W 7,9,~: /~o c~.,o ..... /¢.3, ..: ....... ,',,,r, ,..'..-,..~ , . , , -- ~ ./7~,z~,.;~.~ b,;s~/,~c.er,'~oaT -- 3,/5~.ffq :t, {3 $ ,.P.O'lq'\,',,/..' ....... · . __ , · , · , , , ' . . ' _ " DONE BY: . ,., , CK. BY: ~f '1 ri ' '1 1~ I I I 'I I I I I I I I i . I I I I - DIRECTIONAL_._.SURVEY REPORT FOR MOBIL OIL COY~ANY TYPE OF SURVEY' GYROSCOPIC MULTiSHOT survEY DEPTH: FROM hlOO LEAsE:GRANITE POINT STATE FT. TO FIEu):DRANITE POINT , ??oo WELL NO. 11-24 COUNTY/PARISH KENAI PEN. DATE OF -JOB NO. STATF AT.AAKA' __ STT-~-'I 5] 99 OFFICE: ,,. A.'NCHO.~GE, ALASKA', , , JOa .o. ,SC'./- ,~-I~./9 ? ,~URVEY --:-- MI~ASURED ' CORRECTED DEPTH VERTICAL DEPTH __ ANGLEoF COURSE DIRECTION OF INCLINATION MEASURED COURSE DISPLACEMENT TOTAL DISPLACEMENT TIME INCLIN- DEV. (Z)LIRSE TOTAL COURSE TOTAL ATION OBSERVED CORR· CORRECTED NORTH SOUTH EAST WEST NORTH SOUTH EAST WEST ,/'-Zoo ez_39 3949,Z5 ~ 2//z 5 O~ u/ ] !.78.12-. J 3.34 43°° 90.8/ 404o.o~ 243/¢ $ Od[. u,.) I 4,!.7G ! ~.c/Z ,, 4,¢oo ~_&g.8~ 4zN. g'?,. 2~ $ (")d uJ J 4.3.73 3.0~ .... ¢~',0o 90.2~ !4.?/o.o..q 2sYz. ., $ 0(~ ug ! 4Z,SZ ¢,50 qSoo 89.~ ~z/-?o. o3 2~ ,S O? u2 \ 4-3.5'/ \ 5-~4 14e?.lt 16 · 4?04:) zW Bg 4,,~79_ql ,2.4 .. ,2 n/~ UJ \ ~.(~0\_ 4.$9 ,, ~-ooo 90.07 46.,'~c-). 98>~_ ~¢ ,S 0(~ t,u~ /4.:;.2I'~ 9.5z: /,5,~s.~Z / '79.05 ~/oo g?.4 q 4.'7S'9.¢7 2 (,, '/~ ,3 ¢.5 uj zf.4. o(o 3. g% ~ ...... ,~zoo qb.2(,, 4,?.4>3, q3 25//z ,5' OT ~J ' 42.73 J 5'. 25 :,.~',¢o:~ 9o.~;7 5"o2!,ol ,~ S $ O'g t,U j ,~-1,.~5 / .~' 88) .Y¢'~o 90.2(_,, ,¢12t.27 2£f~ '~ 07 tu] z/-Z.:73 / 5 Z~ /79~.4Z ¢~oc, 9t./8 ,¢39'3.~9 ~4~4 s 07 ~ %.77... I 5,ol /e23~ DONE BY: .......... , . CK. , w~ .o, ~ ~ SURVEY MEAsuRED .............. DEPTH VERTICAL DEPTH ANGLE DIRECTION OV INCLINATION MEASURED COURSE OISPLACEMENY TOTA~ OiSPLA~[MENT CORRECTED , ,~ OV ~OURSE ,,, ................ . ................... . " ~. - toe ................. ...... , .......... ...................... , ........ ...................... , ...... ..................... .............. .... .............................. ~ON[ , , ...... CK. BY: r , ............ l,., , ,,, , ,,L ....... SURVEY MEASURED CORRECTED ~ DEPTH VERTICAL DEPTH ANGLE DIRECTION OF INCLINATION MEASURED COURSE DISPLACEMENT TOTAL DISPLAGEMENT OF COURSE INCLIN- DEV. t ..TIME ~ TOTAL COURSE TOTAL ATION OBSERVED CORR. CORRECTED NORTH SOUTH EAST WEST NORTH SOUTH EAST WEST , ...... .., ,, DONE BY: CK. BY~ I ' D RECT ONAL SURVEY REPORT FOR MOBIL'OIL COMPANY TYPE OF SURVEY: Gyroscopic Multishot SURVEY DEPTH: FROM 630 FT. TO 4000 FT. LEASE: G., P. State WELL NO. 11-24 Granite Point FIELD: COUNTY/PARISH Kenai Penn. Borough DxT£ OF SURVEY 10-~ ~-6 7 OFFICE: ...... Anchorage ~ Alaska , STATF AlaSka ~os NO. SU-3-16174 MEASURED CORRECTED DEPTH VERTICAL DEPTH ANGLE DIRECTION OF INCL~ ~''~ &TION MEASURED COURSE DISPLACEMENT TOTAL DISPLACEME~ -~ OF COURSE _ , .. TIME - INCLIN- DEV. ' ..... ' ' ,~ ~E TOTAL COURSE TOTAL ATION OBSERVED CORR. ~ORRECTED NORTH SOUTH EAST WEST NORTH SOUTH EAST ., , .......... W EST , 2~3-.4-,o /:~oo 97.7Z ;/94.32 12'~_ ~d~ o~ '-'~~ ' ~': ~_ 21./9 I.// &~ 7c; ~2-26~..~ ,I<'700 P~.49 1744.77, ---' ,~ ~ O~ ~ - ~Z~-oo 2too 89. ¢B zo;4.o~ :g(- % 07 ~ 45.~1 ~.~¢ - ~p~ . ...... ~t, ~2.2 z ~.~ ~ 8g >:-2. ~'~-:~ ~j I ..... DONE BY: ~, CK. BY: ' . , . , , '10!3 ' ~EASURED CORRECTED ,,DEPTH VERTICAL DEPTH ANGLE DIRECTION OF INCLINATION MEASURED COURSE DISPLACEMENT TOTAL DISF: L..~EMENT OF COURSE TIME INCLIN- DEV. ' ~ TOTAL COURSE TOTAL ATION OBSERVED CORR, CORRECTED NORTH SOUTH EAST WEST NORTH SOMTH EAST WEST ' ' r ........ *- -,~ · ~.19 6o55&9 126.70 ,. CK. BY: ForTh No. P--4 REV. 9-30-6~ STATE OF ALASKA O]L AND GAS CONSERVATION COMMITTEE MONTHLY RE!PORT OF ~DRILLING AND WORKOVER OPERATIONS SUBMIT IN DEPLICATE ~5. API NUA{ERIC~L CODE 6. LEASE DESIGNAIION A%'D SEqRIAL biO. Granite Point ADL 18761 ,, 1.-" ?. IF INDIAN, ALOTYEE OR TRIBE NA.ME 0IL ~ GAS ~ OTHER ~ELL -- ~ELL 2. N~E 0F OP~TOR 8. ~'IT,F~M OR LEASE N~ME ~obil 0il Corporation ~obil-Union Granite Poin~ 3. ADDRESS OF OPhiR ~ 9. WELL NO. P. O. Box lY~4, Anchorage, Alaska 11-24 4. LOCA~ON O'F W~ 10. FI~ tND P~L, OR WILDCAT Granite Point 2383' South and 1368' East of the NW Corner of Sec. TION, R12W, S.M. 13, 11. SEC., T., R., M,. (BOTTOM HOL~ OBJECTIVE) NW/4, NW/4, Sec. 24 12, PEPdViITNO. REPORT TOTAL D~IPTH AT END OF MONTH, CIz~a~GES IN HOLE SIJE, CASING A/ND CE~IENTING JOBS INCLUDING DEPTH SET A-ND VOLLrMES USED, PERFORATIONS, TEsTs A_ND RESULTS, FISHING JOBS, JUNK IN HOLE A_ND SlDE-TI{ACKED HOLE AND A2~Y OTHER SIGNIFICANT CI4-ANGES IN HOL~ CONDITIONS. J anuary..1.9.6~8 Set retainer at 11,108'. Could not break down~perfs. Perf. 10,750' with 4J/ft. Ran Retrievable Packer. Set at 10,703'. PT perfs. OK. Perf. 4 Jets at 10,400'. PT perfs. OK. Perf. 4 Jets at 9950'. PT perf. OK. Perf. 4 Jets at 9765'. PT Perf. Set BP at 9867'. Set cement Retainer at 9702'. Hole circ. between 9 5/8" and 13 3/8" casing. Set retrievable cementer at 9692'. Squeezed with 30 sex cement. Re-squeeze with 30 sex cement. Re-squeeze with 85 sex cement. C0 to 9867'. PT perfs. OK. CO to 11,108' Perf. 9836/9866, 10,095/10,130, 10,150/ 10,240, 10,315/10,350, 10,535/10,5601 10,580/10,660, 10,675/10,700. Ran 3 1/2" x 3 1/2" tubing. Bottom LS 3 1/2" tubing at 10,416. 7" single hyd. packer at 10 458'. Dual 9 5/8" x 3 1/2" x 3 1/2" hyd. packer at 9,890' Top Dual 9 5/8" x ; 1/2" x 3 1/2" at 9,683'. Bottom SS at 9901'. Landed in ~. Set pkrs. and turned well to production 1/21/68. DIVISION OF MIN~$ a MtNELRALS ANCHORAGE 14. I hereby certify t~hat the f. or~going ~s true and NOTE--Report on this form is ired for each calendar month regardless of the status with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. Form No, P--4 REV. 9-30-67 STATE O,F ALASKA OIL AND GAS CC~NSERVATION COMMITTEE ., MONTHLY'REPORT OF 'DRILLING AND WORKOVER OPERATIONS SUBMIT IN DEPLICATE OIL ~ GA8 [] oTHER WELL WELL 2. NAME OF OPERATOR Mobil 0il Corporation 5. 'AD'DRESS OF OP~i%ATOR P. 0. Box 1734, Anchora§e, Alaska 4. ~.,OCATION O'F WF.I-L 2383' South and 1368' East of the N~ Corner of Sec. TION, R12W, S.M. 13, AP1 NI/~IERICAL CODE LEASE DESIGNATION AND SERIAL NO. Granite Point ADL-18761 7. IF INDIAN, :kLOl l~:J~ OR TRIBE NASIE 8.- I/NIT,FAI~M OR LEASE NAAIE Mobil-Union Granite Point 9. WELL NO. 11-24 10. FIELD A_ND POOL, OR WILDCAT Granite Point 11. SEC., T., R., M., (BOT'rOM HOL~ O~IVE~ NW/4, NW/4, Sec. 24, TION, R12W, S.M. 1~-. PER1VIIT NO. 67 -57 ]3. REPORT TOTAL DEPTH AT END OF MONTH, CI-IA~NGES IN HOLE SI~E, CASING AND CEA/IENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS A1N-D RESULTS. FISHING JOB~, JUNK IN HOLE A_ND SIDE-TI:LACKED HOLE AND A_NY OTHER SIGNIFICANT CIIAN~ IN HOL~ CONDITIONS. December 1967 Drilled 12 1/4" hole to 10,200'. Set 9 5/8" casing at 10,086' and c~mented with 515 sax Class "G" cement. Drilled 8 1/2" hole to 11,800' T.D. Ran 7" liner 9963"= 11798' and cemented with 326 sax Class "G" cement. Cleaned out to 9963' w/8 1/2" bit. Pressure tested top of liner to 5000 p~t. Would not hold. Set cement retainer at 9929'. Squeeze top liner with 50 sax Class "G" cement. Cleaned out to 9963' with 8 1/2" bit. Cleaned out liner w/6" bit. Perforated 11,135' - 11,165' w/4 jets per foot. DST interval 11,135'-11,165'. Rec. 43 bbl. formation water. 1-1-1968 Going in hole with cement retainer to squeeze perfs. 11,135' - 11,165'o D~V~5~ON OF M~f':~S & M~NERAL$ ANCHORAGE- 14. I hereby StO~:DIff fF_~ L-.' 7/~'//~TLE Area Engineer NOTE--Report o. thi~ form is requiret~-f each tale.dar month, r sgardles$ of tl~e status with th~ Division of Mines & Minerals by the ~Sth of the succeeding month, unless otherwise directed. Form No. P--4 STATE OF ALASKA OiL AND GAS CONSERVATION COMMITTEE O~L WELL A~IONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS .o WELL OTHER 2, NA2VIE OF OPEHATOR .1/obi1 0il Corporation · ~ ~J ...... 3. ADDRESS OF OPEKATOR P. 0. Box 1734~ Anchorage, Alaska 4. LOCATION OF WEIA. 2383' South and 1368' East of the NW Corner, Sec. 13, TION, R12W, S.M. SUBMIT 12~ DEPLICATE AP1 NU~IERICAL CODE LEASE DESIGNATION AND SERIAL NO. Granite Point ADL-18761 7 IF INDIAN. ALOTTEE OR TRIBE NA.%IE . . O. UNiT,FAI~M OR LEASE NA~ME Mobil - Union Granite Point 9. WELL NO 11-24 10. FIELD ~ND POOL. OR WILDCAT Granite Point I1. SEC,, T.. R.. M., {BO'I']~OM HO]_2E OBJF_,CTIVE) NW/4 NW/4 Sec. 24, TION, R12W $oMo 1:~ PF'~,,MIT NO, 67 -57 '~3. REPORT TOTAL DEPTH AT END OF ,MONTH. CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOL~S USD. PERFORATIONS TESTS ~&TD PLESULTS. FISHING JOB/~, JUNK IN HOLE A.ND SIDE-TRACKED HOLE ~ ANY OTHEI~ SIGNIFICANT ~ES IN HOL]~ CON'DITIONS. November 1967 Drilled 12 1/4" hole to 10,288'. Stuck Pipe. Spotted 50 bbl. oilo Backed off at 9858'° Left in hole 12 1/4" bit, 12 1/4 Grant Reamer, 7 1/4" x 18t. Monel D.C. 12 1/4" Servco, 7 1/4" x 25' Monel D.Co, 12 1/4" Servco, 7 1/4" x 120' D.C., 12 1/4" Servco, 7 1/4" x 90' D.C., 12 1/4" Servco, 7 1/4" x 90' D.C. WO and BO at 9917'. Recovered 2-7 1/4" x 30' D.C.'s. Ran OEDP to 9917'o Set 150 sax OH Plug. WIH w/12 1/4" bit. Top cement 9736'. Drilled cement to 9746'. Set Dyna- Drill and ~rilled 9756'/9806'. Drilled 9806/9866'. Back in old hole. W/OEDP at:: 9859' set 150 sax OH plug. WIH w/ 12 1/4" bit. Top cement 9694'. Drilled cement 9694'/9725'. WIH w/Dynadrill could not get out of old hole. W/OEDP at 9883'. Set 200 sax OH plug o. WIH w/12 1/4" bit~.,' Found top cmto 9654'. Drilled 9654'/9770'. KO at 9674'° 12/1/67 Drilling sidetracked 12 1/4" hole at 9813'. ,,G~:~ ([~'-(-~, '~.//~.~,.~_L/'1_~ 'rrr~ Area Engineer OA,'~: 12/8/1967 . NOTE--Report on this form I's rec~r/di for each calendar month, regardless of the status of operations, and must be filed In duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. Form No. P--4 lqEV. 9-30-67 STATE OF ALASKA O~L AND GAS CONSERVATION COMMITTEE SUBMIT ]AT DEPLICATE 'M~ ONTH-LY REPORT OF ·DRILLING AND WORKOVER OPERATIONS -~. API NUA~ERICA_L CODE 2. NA~IE OF OP]ERATOR Mobil 0il Corporation 3, ADDRESS OF OPERATOR LEASE DESIGNATION A%'D SEI~IAL NO. Granite Point ADL-18761 1. 7. IF INDIAN, ALOTTEE OR TRIBE NAAIE 01L ~ GAS J~ WELL WELL OTHER s. U~'IT,F~ OR LE~{SE NAaXE Mobil - Union Granite Point P. O. Box 1734~ Anchorage, Alaska 4, LOCATION O,F WELL 2383' South and 1368' East of the NW Corner, Sec. 13, TION, R12W, S.M. 9. WELL NO. 11-24 10. FIELD AND POOL, OR WILDCAT Granite Point I1. SEC., T., R., 1VI., ~BOTTOM HOL~E OBJECTIVE) 1~/4 RW/4 Sec. 24, TION, R12W SoMo 12. PE1RiViIT NO. 67 -57 13. REPORT TOTAL DEPTH AT END OF MONTH, CHAlXTGES IN HOLE SI~E, CASING A1N-D C~A/iENTING JOBS INCLUDING DEPTH SET AlXrD VOLU1VIES USED, PERFORATIONS. TESTS A/ND RESULTS. FISHING JOBS, JIJ-ATK LN HOLE A_ND SIDE-TR3~CI{ED HOLE AND ANY O"I'HER SIGNIFICANT CPIA/~GES IN HOL~ CO1N-DITIONS. November 1967 Drilled 12 1/4" hole to 10,288'. Stuck Pipe. Spotted 50 bbl. oil. Backed off at " 9858'. Left in hole 12 1/4" bit, 12 1~4 Grant Reamer, 7 1/4" x 18L Monel .C. 12 1/4" Servco, 7 1/4" x 25' Monel D.C., 12 1/4" Servco, 7 1/4" x 120' D.C. 12 1/4" Servco, 7 1/4" x 90' D.C., 12 1/4" Servco, 7 1/4" x 90' D.C. WO and BO at 9917'. Recovered 2-7 1/4" x 30' D.C.'s. Ran OEDP to 9917'. Set 150 sax OH Plug. WIH w/12 1/4" bit. Top cement 9736'. Drilled cement to 9746'. Set Dyna- Drill and drilled 9756'/9806'. Drilled 9806/9866'. Back in old hole. W/OEDP at 9859' set 150 sax OH plug. WIH w/ 12 1/4" bit. Top cement 9694'. Drilled cement 9694'/9725'. WIH w/Dynadrill could not get out of old hole. W/OEDP at 9883'. Set 200 sax OH plug. W-IH w/12 1/4" bit. Found top cmt. 9654'. Drilled 9654'/9770'. KO at 9674'. 12/1/67 Drilling sidetracked 12 1/4" hole at 9813'. 14. I hereby cert.4fy tjl~t the foregg~mg is ~rue and q~ect - ,s~ n/Z~J]_~~/. =w= Area Engineer _ ~181~ NOTE--Report on this form ,s re~ir/d for each calendar month, regardless of [~e sta[us with the Division of Mines & Minerals by the [Sth of the Succeeding month, unless othe~ise directed. Form No. P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Effective: July 1, 19~4 LAND IZ3F'F I C E LEASE N U IvtE~E~ LEASE r'lR UNIT NAME LESSEE'S MONTHLY REPORT OF OPERATIONS State Alaska Borough Kenai Field Granite Point T]~e followin~ is a correct report of operations and prod~ction (incl~dir~ drillinff and prod~cinff wells) for tke month of ........ __O__c__~-_°_-b--e-K .................... 19-6-Z--, ............................................................................ ~ ,4 e e r~ t ' s address ........... _P_ _ : _ _ 9_ :__ -B- -°- -x- - - -1- -7- -3- -4- - ........................... C o rt, p a n y .... _ . .~o_ ._b_ _~ _ _ _Q '.l_ l~ . .~_ _ _r- P p. -r- -a- -t- -i- -o~. -l~ y j ........... ..................................... __A__._~_~_o__r_~ g_e_.___A_ ~ ~ ~ ...................... s~.~ ........ _~_:~:__~7/j-~ ........... P I~o ne ........................... 2-_7-_2--7--2--5--5--5- ........................................ ,4 ~ e~ t' s title ........ A~cea__Engine.er__.L/J ............. AND ~4o~ ~4 Gran: Sec. Move, 12 1, ceme~ to 1( and 35O ~WP. . ,, te 24, Ri ointI Sta~e rzo~, RllW, : ole~o 2~'. Drilled ~2 1, Set~3 3~8" ( s=~/ov , ~-men~. prill BAREELS OF OIL ·-:)4 M. ~0 AM - 10- 1et 18" ca.~ ." hole to Lsing at 4( ~llar. D.¥ !d 12 1/4" ll/1/6? ~EAVITY ,032~ 0'. co] ,ole Dri] Cv. F~. oF OAs (In' thousands) Drilled t 635'. C, . Ran ele~ Cemented lar did no' to 8605'. ling at 861 (~ALLONS OF (~ASOLINE RECOVERED .2 1/4" k :mented '.tric lo~ rith 640 close 5' BARREL8 OF WA~ER (If none, so state) ,ole to 6 'ith 800 s. Re am sax Clas Squeeze, REMARKS (If drillinf~, depth; if shut down, oau~e; d~te and reeult o! teet for gasoline oontent of 0 '. Reamed ax class "G" :d 12 1/4" hole "G" thru shoe DV collar with NOTE.--There were ........... .N..0. ............................... runs or sales of oil; ................ N..0. ........................... M cu. ft. of gas sold; ........................ N..Q .............................. runs or sales of gasoline during the month. (Write "no" where applicable.) of the status of operations, and must fiNedNOTE'--Rep°rtin duplicate°nwiththisthef°rmDivisioniS requiredof for each calendar month, regardless ~,a ~c~ ~x_~,r~=1E Mines & Minerals by the 6th of the succeeding month, [~,,]--~[,,tl~.T~,l~ [2 be directed. NOV 1 3 1967 DIVISION OF MINES & MINERAL~ ANCHORAGE lb~.Looed plesae f~ind ~ apprated app~L,~f~n for permit co drill the zebzenced roll. ~ Well ~ and ~,ehipa m uoc required. z- September 21, 1967 Please mail us a receipt, for check #AA'9032. Thank you. Mobil Oil Corporation ~u~ of L~bor ~sl~ull, Supervisor September 25, 1967 Granite Hob~! Oil Corporation; ~lmd is & ~py of the approved ippliutioa ~o drill for eh~ above ¢sp~ioued wll. ~Jr Form, ~' _'-:STATE OFf'~ALA~SKA reverse side) OIL-AND GAS cONSERVATiON. COMMIS~iON',~.. APPLICATION ~FOR"PE~RMiT TO'DRILL, DEEPENS-OR~ 'PLUG .BACK ~YPEOF WORK ~ .... ' > ..... ".':~ ~ : ' ' "::~' ' ~ ':~ ' ~;' ' " ..... : DRILL ~ : ;~ DEEPEN'. ' ~ L .~ ~ ~ ?. - ,.. q t . .~. , . , · '' -* ~ cF* t ,' " : sa~'·Mobil ~ o,,~*~.,0il Corpora cioa .~ u., .-.~ AP1 50-133=2 004& ~- _ ..... _. -_ :SUBMIT. ~ TR~'~ ATE*. Effective: J~uly 1,' 1964 ~ ~r ' (Other instructions on'- . 5~ LEASE DESIONATION' AND SERIAL NO. . State ~ADL 1876,I 6. 'IF~INDIAN, ALLOTTEE ~R ~R~BE NA ME FARM OR LEASE 'NAME Uni0n=Mobil State #1 ~J~'G~anite PSifft State #11-24 ~. ADDRESS OF OPERATOR . ,,~: ~ ....... 700 G Street, Anchorage, Alaska .... 99501 ......... " -. ~0. Fzs~ A~ ~oo,.. o~ WILDCAT 4. LOCATION::OF WELr.-(Report. locati0n cl~rly-and:ln a~ordance wl~-a~y;S~ter~ui'rements.*) -' [ Granlte 'Point:Middle Kenai At s r i ~ [ 1~. S~C.,~.,R,M.,OaOLK. ~ S & 1368 E from ~ CDr Sec. At pr°p°'ed prod. zon; (T;~ '~i;"S s:793'lg 'fr;~"~ C'or'.':s';C, 24, T10N, c.R~, TION, R12W. S.M. Cook Inlet R12W, S.M. (T.D.) 2112'S & 623'E from ~4.DISTANCE IN MILES AND DIRECTION FROM NEAREBT TOWN OR POST OFFICE~ SH STATE Cook Inlet - Approx. 12 mi. So. of Tyonek Indian Village / Kenai ~ Alaska ~. m~c~ ~aoa ~ao~o~* 3i68' ~rom South LOCATION TO NEAREST - Bom,dr Sec 24 TI0 ~O,Hm w~ ~o~,~ o~ ~ ~, ~. Y ' ' ~' ' 5089 160 (~eo to nearest drlg. unit line~ tf any) R12W. S.M. I~ ~g~ANCE FRO~ PaOPOS~m LOCaWmN* - / ~ ~~W~ - 20. ROW~g ~a CabLE WOOLS "~o ~s, w~, ~, co~, 2600 at Top o~ ~ ~, o~ ,ms m~, ~. of Zone ] 12,100' M.D. Rotary 21. E~VA~0NS (Show whe~er DF, RT, GR, e~.) 22[ ~PROX. DATE WORK WIlL START* 105.9 ' above MLLW (K. B. ) September 26, 1967 23. PROPOSED CASING AND CEMENTING PROGRAM I SIZE20II°F HOLE . . [[. 17 1/2" 12 1/4". SIZE OF CASING WEIGHT PER FOOT 18" OD 70.56# 13 3/8" OD 61# 9 5/8" OD 40 - 47# SETTING DEPTH 600±MD 4000+_MD 12,100+-lVlD QUANTITY OF CEMEN~ . 1250 sax .2700 sax 1250 sax Well will be drilled 4500' Sl0°W from surface to T.D. at 12,100' M.D. anticipate Middle Kenai zone at 9660' - 12,100' M.D. (8900' - 10,100 S.S.) BOP Program: 600' to 4000': 4000' to T.D. : 20 3/4" Hydril "MSP", 2000 psi W0G 13 5/8" Hydril "GK" 5000 psi WOG and 13 5/8" · ' .Cameron "U" triple 5000 psi WOG IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen or plug back, give data on present productive zone and proposed new .productive zone. If proposal is to drill or deepen directionaily, give pertinent data on subsurface locations and measured and true vertical depths. ' Give blowout preventer program, if any. 24. I her~:rt~;~smNn~ and C~rrect'TITLE (This space for Federal Or State o~ce use)J/- PERMIT NO. ' APPROVED B, CONDITIONS OF APPROVAL, IF ANY: TITLE Area Engineer . DATE 9/21/1967 APPROVAL DATE THoMAs R. MARSHALL, ~<~cutive Secretory Ato~ko Oil & Gas Conservation ' ~mmittee RECEIVED AP1 50-133-20046 *See Instructions On Reverse Side SEP 2, 2 196'1 DIVISION OF MINES & MINERAI.~ i { i - + 27 1 T, IINI 1 i i i;t. 12 W. 26 34 35 T. tON, I0 UNION-MOBIL 18765 i5 22 R. 12W. UNION-MOBIL Stet · No. t 31- ~4 · 14 23 PAN-AM 1874 5 36 t 3t PAN-AM '874~ I I I PAN I 29 _',2 R. Il W. 12 3 · I J Platform "A" ' MOBIL .~ - ~ ~13-13 · 33-13 I 793' II -24 ! PROPOSED LOC. 1 STATE AiDL IB761 HUNT 17580 19 MOB!L. X : 26.~, 5'~.'~ Y ': Z.544,55~ 17 2O SUPERIOR -'TEXACO 2i862 MOBIL OIL CORPORATION GRANITE POINT FIELD COOK INLET, ALASKA STATE ADL 18761 WELL NO. 11-24 SCALE' JF'-- DATE' 9/20/67