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196-075
• • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑✓ , Suspended❑ 1 b.Well Class: 20AAC 25.105 20MC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAGE] WDSPL❑ No.of Completions: Service Q . Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,Susp., or 14. Permit to Drill Number/ Sundry: Hilcorp Alaska, LLC Aband.: 8/15/2017 196-075/317-163 w 3.Address: 7. Date Spudded: 15.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 April 9, 1996 50-733-20095-02-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 2379'FNL, 1375'FWL, Sec 13,T10N, R12W,SM,AK May 28, 1996 Granite Pt St 22-13RD2 , Top of Productive Interval: 9. Ref Elevations: KB: 115' 17. Field/Pool(s):Granite Point Field N/A GL:0 BF:0 Middle Kenai Oil Pool , Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1995'FNL,2141'FWL,Sec 18,T1 ON, R11 W,SM,AK 8,495'MD/8,151'TVD . ADL0018761 . 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 263405 y- 2544551 Zone- 4 13,934'MD/10,811'TVD' N/A TPI: x- y- Zone- 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 269459 y- 2544812 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 N/A (ft MSL) 8,495'MD/8,151'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 RECEIVED OCT 2 0 2017 OGCC 23. CASING,LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT. PULLED 26" Surface 294' Surface 294' Driven 18" 70.6# B Surface 600' Surface 598' 22" 1050 sx 13-3/8' 61# J-55 Surface 3,989' Surface 3,973' 16" 735 ft3 9-5/8" 43.5# N-80 Surface 6,643' Surface 6,616' 12-1/4" 950 ft3 7" 29# L-80 6,360' 8,495'(TOW) 6,334' 8,151' 8-1/2" 345 sx 24.Open to production or injection? Yes ❑ No Q 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MDIfVD) Size and Number; Date Perfd): N/A A1sP`N0aNE0_ 26.ACID, FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Yes❑ No 0 SCANNED 'JAN 1 0 20!8 $ff si rt Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED Lt- 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: N/A Test Period �► Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. _24-Hour Rate — Form 10-407 Revised 5/2017CONTINUED ON PAGE 2 Submit ORIGINIAL only �'Kd l iiiIii7- I l-6,—/7 , (Kr,(7 RBB MS A V O 2 4 2017 • • 28.CORE DATA Conventional Core(s): Yes ❑ No El 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: G 31. List of Attachments: Wellbore Schematic, Decomplete 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: Cdln er .hilcorp.com AuthorizedContact Phone: 777-8389 Signature: �C ' Date: 10[/ /71)!7 02 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 Granite Point Platform . in HO • Well: Granite Pt St 22-13RD2 Abandoned on:8/15/17 Abandoned Schematic PTD: 196-075 API: 50-733-20095-02-00 Hilcorp Alaska,LLC CASING DETAIL Size Wt Grade Conn ID Top Btm 26j l 26" Inside Conductor Surf 294' 18" 70.59 B Surf 600' 13-3/8" 61 J-55 BTC 12.515" Surf 3,989' 9-5/8" 40&43.5 N-80 BTC&8rnd Surf 6,643'TOW is' 7" 29 L-80 BTC 6.184" 6,360' 8,495'(KOP) 4-1/2" 12.6 L-80 SC-BTC 3.958" 11,215' 13,922' (slotted) 13-3/8" A II JEWELRY DETAIL No Depth Depth ID OD Item (MD) (TVD) 8,514' CIBP(set for whipstock) 9-5/8" 1 10,325' Halliburton EZSV Cement Retainer TOW @8,495' BOW @8,508' 2 10,333' 9,219' 3.250" 5.820" 7"Baker SC-2P Retrievable Packer 3 10,338' 9,222' 3.250" 5.460" 80-32 Seal-bore Extension(15.75') 4 10,386' 9,253' 2.313" Otis X-Nipple 4111W-41.11 C-1.9 5 10,420' 9,275' 2.441" 3.500" Wireline Re-entry Guide CIBP @±8,514' PERFORATION DETAIL TOC @~10,225' Zone Top Btm Top FT Date Status Comment (MD) (MD) (TVD) (TVD) r z C2 10,534' 10,602' 9,351' 9,396' 68' 10/11/1996 Isolated 2-1/8"EJ '_ -1 4 cz, C5 11,490' 11,530' 9,976' 9,997' 40' 5/28/1996 Isolated 2-1/8"H.C. ® _„ C5 11,550' 11,570' 10,007' 10,017' 20' 5/28/1996 Isolated 2-1/8"H.C. ®, ` -- 32 C5 11,610' 11,650' 10,037' 10,055' 40' 5/28/1996 Isolated m 4*.*t42 1/8"H.C. .��u,, s �a-AT:A 1wi .-*w-C2 Sand s G:r V':1;'''', 4 t 4,,.,b Notes: ''c, GR/CCL ran in 12/97 shows tbg tail NOT present , �x�kp sand 10/11/2000-Tagged fill at 11,142'(WLM) a : r 4-1/2" "","E'' "' PBTD:???' TD:13,934' MAX HOLE ANGLE=83° Updated By:CJD 10/20/17 • • Hilcorp Energy Company Composite Report Well Name: GPF GP 22-13RD3 Field: County/State: ,Alaska (LAT/LONG): ?Nation(RKB): API#: Spud Date: Job Name: 1711827P GP 22-13RD3 PreDrill Contractor AFE#: 1711827P �q,� + C,/ AFE$: $1,681,386 ''"L`-� L u4( ictivity Date :i :: 'Otw timrtiiat r 5/15/2017 Continue to work on moncla 404 rig and service the tong lines hyd cylinders,primer and paint 404 doghouse,continue cleaning and scrubing platform deck around rig 5/16/2017 Continue sericing moncla 404 rig rebuild mud manifold,paining the 404 dog house,cleaning up deck w/daylight crew only 5/17/2017 Continue servicing Moncla 404 Rig working on the drawwork and the gear shifting box with moncla mechanic and repairing cables in derrick and continue painting around rig continue with the logistice with granite point well 22-13 rd2,_organizing for the move 5/18/2017 Continued demobing from 24-13 well, 5/27/2017 Continued demobing w/o package from 24-13.,Rigged up and attempted to skid-called prod mechanic to check power pack. Drained water contaminated oil from hyd power pack,changed filters,repaired leaks and replaced broken 4-way connector then attempted to skid rig-one hyd ram would function and one would not. Located another hyd power pack on Dillion and hyd rams at OSK. Made arrangements to have those items delivered to GPP. Suspended skidding operation.,R/U Pollard ELine w/full lubricator-M/U 2.75"jet cutter w/CCL&wt bar-TIH thru tree and tagged high at 8,795-P/U above tb collar and fired cutter at 8,770'. POOH. Attempt to SI swab valve,jet cutter tool suite across tree valves. Work wire,unable to pull tool suite through tree and into lubricator,tagging out at tubing hanger. RIH to place tool suite below tubing hanger.,R/U to circulate well with FIW pumping to tubing taking returns from casing to production well clean tank. Start pump at 1.0 bpm,0 psi. Pump 150 bbl(4200 stks) Increase pump rate to 1.50 bpm,0 psi. 215 bbl away(6000 stks)increase pump rate to 2.0 bpm,40 psi,263 FIW away,2.0 bpm 575 psi,fluid returns to surface. Stop pump,well on vacuum. ELU works wire a surface,work tools suite past tubing hanger and tree valves and into lubricator. Shut swab valve, R/D ELU,all tools returned to surface,Resume circulating well,pumping to tubing,taking returns from casing to production well clean tank at 2.0 bpm 40 psi(rate dictated by production operator),Halco 1/4 turn valve on return line leaking,stop pump and replace valve. Resume well circulation,2.0 bpm 155 psi(rate dictated by production operator),Drop pump rate, 1.50 bpm 54 psi,continue to circulate(rate dictated by production operator). Shutdown pump at 483 bbls pumped and well was on vacuum.,NOS rep dismantled tree down to lowest valve inorder to set BPV. 5/28/2017 N/D tree partially leaving one valve above tb head-installed BPV.,Skidded rig over 22-13 well with use of chain horses,crane, 1-hyd ram and power pack.,Finished N/D tree-NOS rep cleared scale from hanger threads and installed ported test sub. Moved koomey unit and choke house into position. Bruce welder came onboard to build a foot for 2nd hyd ram(also repaired fingers in Moncla derrick).,N/U 13 5/8"5M BOPE-continued moving equipment into position,Torqueing BOPE flange bolts to spec. Stand up and scope out derrick. Secure guide lines.,Run koomey lines to BOPE. Run choke and kill lines to mud cross and rig up choke house. Run pump and return lines. Set rig floor and stairs in place.Secure carriage lines. Pressure up koomey. Set heater and fuel tank in place.,Hang tongs. Move handling tools,3-1/2"test joint test joint,IBOP,TIW and pump-in sub to floor.,Load stack with FIW. Shell test 3500 psi,tighten coflex hose R24 flange connection leak,repeat test successfully.,M/U safety valve, IBOP and pump-in sub to 3-1/2"test jt w/ported sub on bottom, NOS rep on floor.,Pre-testing BOPE per HAK and AOGCC regulations and requirements. 5/29/2017 Finished w/BOPE pretest.,Clear,cleaned,organized deck area,driller's shack,rig floor while awaiting arrival of State man.. Crane crew made room arriving equipment Tested all BOPE to 2502si low 35002si high(including annular)as per Sundry in accordance to AOGCC and Hilcorp requirements-performed successful koomey draw-down test. Test witnessed by Bryan Bixby/AOGCC. 1100 hrs worked M/V Titon offloading KOTs fishing tools, DCs,workstring and pipe racks.,Broke down test jt-NOS rep pulled BPV-B/O holdown pins. M/U KOTs spear w/grapple for 2.992"I.D.tb on jt of 3 1/2"EUE tb. Speared into tb below hanger and pull hanger to surface weighing 82k-NOS worked and laid down hanger.,Filled hole with 183 bbls FIW. SOOH w/recovered 3 1/2"9.2#L- 80 BTC production tb from jet cut at 8,770'.,28 joints 3-1/2",9.2#recovered and laid down(869'). Fill hole with 35 bbl FIW Loss rate=0.34 BPM(20 bbl/hr),Continue POOH with 3 1/2"9.2#L-80 BTC production tb. Pump 10 bbl FIW every 30 joints. 85 joints 3-1/2",9.2#recovered and laid down(2,650'). Fill hole with 32.7 bbl FIW Loss rate=0.19 BPM(11.7 bbl/hr),Pitting at Joints 85/86 pin-box connection(photos saved to O drive) Continue POOH with 3 1/2"9.2#L-80 BTC production tb. Pump 6 bbl FIW every 30 joints. 03:30 work M/V Titan back loading loaded 3-1/2 pipe rack and valves/hanger basket,offload empty pipe rack. 223 of 280 jts laid down at report time. Fluid losses running—12 bph. Total FIW losses=294 bbls. • 5/30/2017 Finished POOH with recovered 3 1/2"9.2#L-80 BTC production string to ELine jet cut(278 jts+5-pups+cut piece+elev=8,768.14')(PM).,Cleared and cleaned rig floor-changed out tb tongs.,M/U KOTs BHA#1 (8 1/2"X 2"Varel rock bit,5 1/4"x 1 1/2"casing scraper,4-1/2 Reg x 3-1/2 IF bit sub,3-1/2"IF pin x 3-1/2"PH-6 box XO sub). TIH w/BHA picking up 3-1/2", 12.95#, P110, PH-6 work string. Lightly tag top of Baker SC-1R ret.packer at 4,940'. (159 singles-4.53') P/U 1',M/U safety valve and pump-in sub.,Line up to reverse out returns across shaker. Circulate with FIW,3.0 BPM,64 bbl(1800 stks)returns to surface. Reverse circulate at 2.52 BPM,600 psi. 2230 hrs worked M/V off loading mixing tank,remainder of 3-1/2"PH6 tbg,5"&7"test jts,McCoy tongs,handling tools,pill materials and Baker pulling tool. Back load partial rack 3-1/2",9.2#L-80 BTC 2245 production electrician wiring mix tank to platform power.,216 bbls.away,2.82 bpm,750 psi. Fluid Loss Rate-28 bbl/hr Mixing 40 bbl Sized Salt Pill Continue working boat,500 bbl FIW circulated(14,000 stks). Continue to circulate at 2.20 bpm,475 psi while continuing to mix 40 bbl Sized Salt Pill. Fluid Loss Rate-32 bbl/hr Release M/V Titan. Shutdown pump after 820 bbls FIW pumped.,Lined up to pump 40 bbl sized salt pill-worked thru minor pump issue. Pumping pill at report time. Fluid losses presently running 30 bph. Total FIW pumped away=636 bbls 5/31/2017 Circ 40 bbls hi-visc sized salt pill to bit at 4,940'-closed returns and bullheaded pill to end of tb at 10,420'w/154 bbls at 1 bpm 900-1200 psi. Shutdown pump and settled well(-3 bbl returns).,POOH w/8 1/2"bit&scraper pumping 4 bbls every 20 stands. B/D BHA.,Cleared rig floor. R/U Pollard ELine-N/U 13 5/8"x 7 1/16"spool- install 7 1/16"flange f/knockup x packoff. M/U 3.75"jet cutter(f/5"15#pipe)w/CCL&wt bar-TIH to 6,550'and pulled tie-in strip-fired cutter at 6,494',5'above FA-1 pkr. POOH&R/D ELine-N/D 13 5/8"x 7 1/16"spool.,M/U BHA#2(BOT Retrieving Tool,4 3/4"x 2 1/4"O&B Jars,6-4 3/4"x 2 1/4"DCs,4 3/4"x 2 1/4"Acc Jar,3-1/2"IF pin X 3-1/2" PH-6 box). Filled hole w/52 bbls FIW.,TIH with BHA#2 on 3-1/2"PH-6, 12.95#, P110 work string. TIH with 152 jts 3-1/2", UpW=68K, DownW=64K. PU 10'pup 3-1/2"PH-6 and tag top of SC-1R packer at 4940' Latch packer, PUH=78K,slack off, PUH=86K let oil jar hit PUH free travelling at 107K PUH laying down 10 jts,top of packer at 4665',M/U hanger to 3-1/2"PH-6 work string(3-1/2 PH-6 pin X 3-1/2"IBT box(0.85'),3-1/2"IBT pup(5.80'),hanger head with 2-way check(1.44') M/U 3-1/2"PH-6 landing joint with 3-1/2"IBT X-over on bottom to hanger Fill hole with 16 bbl FIW-fluid loss rate-7 bbl/hr TIH landing hanger while displacing fluid to well clean tank, run in lock down screws,break out landing joint.,Clear rig floor,rig down and remove tongs. Rig down rig floor and off driller side stairs. Closed and locked blind rams-N/D Hydril,Clean and organize rig and drill deck. 141 bbls of FIW lost last 24 hrs=777 total losses. 6/1/2017 Slipped and cut 120'of drill line.,Cleaning and organizing work area-Moncla mechanic onboard adjusting drive chain on draw-works and changing out air hoist.,Offloaded M/V Titon receiving Knight single gate preventer Idd w/7"ram blocks,koomey hoses,Moncla air hoist,subs needed for 5"&7"test jts,N/U 13 5/8"x 5M single stack preventer and annular-hooked up koomey lines Mounted rig floor and off-driller side steps. Hang Gill tongs and connect power pack hydraulic lines. Move handling tools to rig floor,prepping for BOPE pre-test.,M/U IBOP,safety valve,pump-in sub,and 3-1/2"test joint with 3-1/2"BTC ported sub on bottom Fill stack w/FIW. Open casing valve,well on vacuum.,Pre-testing BOPE to HAK and AOGCC regulations and requirements.,Pulled and laid down 3-1/2"test joint. M/U IBOP,safety valve,pump-in sub,X-overs and 5"test joint with 3-1/2"BTC ported sub on bottom. Continue pre-testing BOPE to HAK and AOGCC regulations and requirements.,Pulled and laid down 5"test joint. M/U IBOP,safety valve,pump-in sub,X-overs and 7"test joint with 3-1/2"BTC ported sub on bottom. Continue pre-testing BOPE to HAK and AOGCC regulations and requirements.,Successful completion of BOPE pre-test. Pulled and laid down 7"test joint. M/U IBOP,safety valve,pump-in sub to 3-1/2"test joint with 3-1/2"BTC ported sub on bottom. Install 3-1/2"test joint prepping for AOGCC witnessed BOPE test.,Clean,organize and continue prep for AOGCC witnessed BOPE test this morning. Well shutin last 24 hrs-total FIW pumped away=777 bbls 6/2/2017 Clean,organize and prep for witnessed BOPE test. Hydraulic pump on tong power pack failed-disconnected unit.,Test all BOPE to 250 psi low 3500 psi high as per Sundry in accordance with AOGCC&Hilcorp requirements. Tested w/3 1/2,5&7"pipe-performed successful koomey draw down test. Test witnessed by Mr.Matt Herrera/AOGCC.,B/D test equipment and cleared floor of all unneeded subs and tools. Hooked up replacement hyd tong power pack. Laid down 7"test joint. M/U 3-1/2"PH-6 landing joint with 3-1/2"BTC X-over on bottom.,Open casing valve,well static. Pull hanger to rig floor,hanger missing all(2)sealing 0-rings. Laid down 3-1/2"landing joint. Laid down hanger,3-1/2"pup joint and 3-1/2"BTC X 3-1/2"PH-6 X-over. Fill hole with FIW,3.0 bpm 60 psi,92 bbl.to fill hole.,POOH standing back 3-1/2"PH-6, 12.95#, P110 work string. Fill hole WI FIW every 20 stands.,KOT Acc.Jars to floor. 71 stands 3-1/2"PH-6 racked back to derrick. B/D KOT BHA,racking back drill collars and laying down KOT BHA components with KOT rep present.,BOT pulling tool and SC-1R packer to floor. R/D Gill tongs. PJSM with Moncla,Weatherford, KOT and Peak. R/U Weatherford tongs and power pack,move casing handling tools to floor.,Laid down BOT pulling tool,SC-1R packer,mill out extension and X-over. POOH laying down 7"29"L-80 BTC casing pumping 5 bbl FIW every 10 joints. 14 of 31 jts of 7"laid down at report time. 146 bbls FIW pumped away last 24 hrs=923 bbls total loss to well. • • 6/3/2017 Finished POOH laying down 31-jts of 7"29#&5-jts 5"15#casing+4.63'of 5"(jet cut)pup jt=1,558.05'recovery of scab liner. RID Weatherford tongs and handling equipment.,Setup tb tongs and handling tools on rig floor. M/U BHA#3(3 1/4"x 3/4"spear w/grapple f/5"15#casing,4 3/4"x 1 3/8"XO,4 3/4"x 2 1/4"B&O Jars,6-4 3/4"x 2 1/4"DCs,4 3/4"x 2 1/4"Acc Jar,4 3/4"x 2 1/4"XO=226.40').,TIH w/BHA on 3 1/2"12.95#P-110 PH-6 workstring to 4,816' (74 stands that were in derrick)-picked up 11 previously strapped singles then strapped,drifted and M/U singles to just above stub.,200 joint in hole,P/U power swivel. Set power swivel torque 6000 FPT max. Fill hole with 15 bbl FIW.,TIH with joints 201 -203. Free Spin Torque=0-100 FPT,DownW=68K,UpW= 72K. On joint 203 tag top of cut 5"15#at 6,498',set 2K weight down hole. Continue TIH to 6521',P/U joint 204,and work down to set down depth at 6,532'. Fish latched,work pipe 60K-90K without movement. P/U to 82K,start rotating with 300-400 FPT. 10 full rotations K-22 locator free. Laid down joint 204, rig down power swivel.,PUH 20'with joint 203 start pulling 20K over string weight. Continue PUH and over pull falls off. Laid down joint 203.,POOH standing back 3-1/2"PH-6 workstring in derrick pumping 4 bbl every 20 stands. KOT BHA#3 at floor,break down BHA laying down KOT components,stand back drill collars KOT spear to floor with 5"15#cut casing stub and K-anchor attached(photos of fish on O-drive).,Installed 7 1/16"stripper head to Hydrill. Move KOT mill to rig floor&M/U BHA#4(6"x 2 1/4"Junk Mill,4 3/4"x 2 1/4"B&O Jars,6-4 3/4"x 2 1/4"DCs,4 3/4"x 2 1/4"Acc Jar,4 3/4"x 2 1/4"XO= 225.33').,TIN w/BHA on 3 1/2"12.95#P-110 workstring-541'in hole at report time. 6/4/2017 Continued TIH w/KOT BHA#4(6"x 2 1/4"Junk Mill,4 3/4"x 2 1/4"B&O Jars,6-4 3/4"x 2 1/4"DCs,4 3/4"x 2 1/4"Acc Jar,4 3/4"x 2 1/4"XO=225.33')to 6,456'(100 stands+single).,P/U power swivel w/single#202-installed stripping rubber and M/U to string-PUW 90k SOW 84k Torq 2000 FPT RPMs 90 2 BPM 130 psi. Eased down and tagged plug at 6,503',Mllled from 6,503 to 6,506'and pkr broke free-pushed it down hole to 6,582'-L/D swivel and remove stripping rubber..,Chased remains of pkr down hole P/U singles(strapping,drifting,M/U to 6000 FPT)to 8,792'(276 joints+9.80'joint 277). R/U power swivel and install stripping rubber. Break circulation with 24 bbl FIW at 2 bpm 225psi Rotary weight=102K Up/Down at 90 RPMs-free torque=3000 FPT-chalk mark joint 277 for 8,795'max depth,Start milling 2.23 bpm 260 psi-mill from 8,792'to 8,795'.Stop pump-PUH,PUW=106K,TIN and soft tag at 8,795',Circulate hole clean with 200 bbl FIW at 2.80 bpm 370 psi-R/D power swivel and remove stripping rubber head-Laid down joint 277.,POOH standing back 3-1/2"12.95#PH-6 work string in derrick pumping 4 bbl every 20 stands. 117 of 138 stands OOH at report time=1,503'. Fluid losses currently at 10 bph. 182 bbls FIW pumped away last 24 hrs Total FIW lost=1165 bbls. 6/5/2017 Finished POOH w/BHA#4(junk mill)-B/O mill(pics in'0'drive)-indication of 3 1/2"tb wear pattern on mill face-mill-30%worn.,M/U KOT BHA#5(5 3/4"x 2 3/4"overshot Idd w/3 1/2"basket grapple,4 3/4"x 2 1/4"B&O Jars,6-4 3/4"x 2 1/4"DCs,4 3/4"x 2 1/4"Acc Jar,4 3/4"x 2 1/4"XO=227.39'). TIH to 8,872'(138 stands).,PUW 108k SOW 92k-P/U pups and latched fish at 8,795'-hit jars one time at 140k&seals pulled from pkr. Laid down pups-B/O safety valve.,POOH w/recovered 3 1/2"BTC production string-standing back 3-1/2"PH-6 work string. KOT BHA#4 at floor,break down and laid down KOT BHA, drill collars. KOT overshot and cut joint to floor,laid down over shot and cut joint as one.,POOH with 3-1/2"9.2#BTC tubing standing back 12 stands, Laid down remaining 3-1/2"BTC tubing.,Clean and clear floor. Strap recovered 3-1/2"9.2#L-80 BTC tubing.(12 stands+24 joints+X-over,jet cut piece and seals =1,541.16') Move KOT BHA#5 bit and scraper BHA to floor. M/U KOT BHA#5(6"rock bit,5-1/4"X 1-1/2"casing scraper,4-3/4"X 1-1/2"bit sub,4-3/4"X 2- 11/16"X-over),TIH with KOT BHA#5 bit and scraper on 12 stands(757.62')3-1/2"9.2"L-80 BTC recovered tubing. Rabbit each stand of 3-1/2"BTC tubing out of derrick. Continue TIH with BHA#5 on 3-1/2"12.95#P-110 PH-6 work string,P/U 3 1/2"PH-6 workstring singles to reach depth-10,067'at report time. Fluid losses-10 bph 62 bbls FIW pumped away last 24 hrs Total FIW lost=1227 6/6/2017 Continued in hole w/6"bit&scraper tagging SC-2P pkr at 10,352'(PM). P/U to 10,347'and broke off single-lined up to rev.,Rev circulated 8000 strokes(2- hole volumes in 7"+tb)at 2.75 bpm 380 psi taking returns across shaker. Shutdown pump and broke off Iines.,POOH w/bit&scraper standing back 154 stands of 3 1/2"12.95#P-110 PH-6 workstring-pumping displacement.,Laid down 24 jts of 3 1/2"9.2#L-80 BTC production tb then B/D bit&scraper BHA. Filled hole w/38 bbls FIW.,Installed 13 5/8"x 7 1/16"spool f/WL packoff adapter. R/U Pollard ELine and TIH w/Gamma Ray/Sector Bond Tool to 10,000'- logged from 10,000'to 7,500'(7"29#)then logged from 6,350'to 5,400" (9 5/8"40&43.5#)casing- POH.,B/O bond tool and M/U PDS(memory)casing caliper tool-RIH T/9,000' and logged to surface-down loaded tool.,Rig down Pollard ELine- M/U Halb running tool/cement stinger&7"EZSV on PH-6 workstring(filled hole @ 02:00 w/40.5 bbls FIW).,TIH running EZSV on PH-6 12.95#P-110 workstring @ 40 sec stand as directed by Halb rep. 61 stands in hole at report time=3,793'. Fluid losses-10 bph 137 bbls FIW pumped away last 24 hrs Total FIW lost=1364 bbls 6/7/2017 Continued RIH w/Halb 5.5"EZSV from 3,793'on 3 1/2"12.95#P-110 PH-6 workstring to 9,619.22'(155 stands).,Picked up 21-3 1/2"12.95#P-110 PH-6 singles to reached a depth of 10,269'.,M/U hanger&XOs on btm of test jt then M/U in string-landed same in tubing head. M/U pumpin,safety valve and IBOP in top of test jt-filled stack and purged air-shell tested to 3500 psi.,Tested BOPE to 250 psi low 3500 psi high as per Sundry in accordance to AOGCC& Hilcorp guidelines-performed successful koomey draw-down test. Witness waived by Mr.Jim Regg 9:57 AM 6/6/17.,B/D test jt and M/U landing jt in hanger- pulled hanger w/XOs to surface and B/O same.Ran in 2-more singles to 10,325'(166 stands+1-single).,PUW 120k SOW 95k-set Halb EZSV at 10,325' with 35 RRHT at tool-pulled 40k over to shear pin then another 25 RRHT to set tool for use.,POH w/cement stinger/lay down stinger.,M/U Halb 9 5/8"RTTS and service rig and hook up hydraulics tong line cables for manual tongs,Continued RIH w/Halb 9 5/8"RTTS T/6339',R/U head pin and set 9 5/8"RTTS @ 6329' up wt 78K down wt 72K and close 3 1/2"pipe rams,Pressured up to 2600 PSI on 9 5/8"casing-held for 33 mins on chart-lost-50#s. 9 5/8" X 13 3/8"increased to 290 PSI and held. Presently lining up to test downhole Fluid losses presently 0 bph 24 bbls FIW pumped away last 24 hrs Total FIW lost=1388 bbls 6/8/2017 Pressured up to 2770 psi testing 9 5/8"annulus to surface f/60 mins-solid test. Released pressure then pressured up to 2550 psi down tb(testing top of liner (6,360')and 7"liner to EZSV at 10,325'-held on chart f/36 mins-solid test, Released pressure and released RTTS tool-pressured up down annulus to 2730 / psi f/34 mins on chart-solid test. Released pressure.,Changed cylinder on air slips and prepped to POH.,POH with RTTS tool as directed by Halb rep.,B/D 6t 5v RTTS tool-M/U cement stinger,RIH W/Halb stinger t/10271',Service rig repair seals in mud pump,repair air pump in accumulatorand paint hilcorp choke house for the 404 rig Staying in touch with Halliburton at the Osprey platform for the cement unit to be Released. 6/9/2017 Performed maintenance on rig,organized and cleaned while waiting on Halb cementing crew&equipment. Crew onboard at 1230 hrs.,Offloaded and spotted cementing equipment-R/U same. Tied rig pump in and broke circ(LW)at 2 bpm 180 psi. Eased down and stung into EZSV,PJSM w/crew-started pumping and established injection rate @ 1 bbl min 900 psi(applied 500 psi to annulus w/rig pump)- • u•-• I •• • ••• 'is ... I- -• /FIW- final injection rate 3/4 bbl min 2000 psi-shut down afer 30 bbls injected below the retainer- bleed down annulus pres t/0-unstung from EZSV and spotted 10 bbls of cement on top of the retainer. POH setting back 7 stds in derrick t/9901'.,Reverse circulate 2 x B/U @ 3 bbls min 550 psi-r/d halb-loaded out MN w/ Halb equip and personnel-released boat @ 2130 Hrs .,POH standing back 18 stands then began laying down PH-6 workstring,using crane moving five per bundle on deck. 176 of 333 jts laid down at report time=EOT at 4,874'. No FIW losses to well last 24 hrs. Total losses f/job=1388 bbls • • 6/10/2017 Finished POH from 4,874'laying down 3 1/2"PH-6 workstring. B/D UO Halb cement stinger.,Cleared and cleaned floor-filled hole and closed blinds- pressured up to 2850 psi and held for 46 mins-solid test.,R/U Pollard ELine w/CCL&junk basket w/5.74"gauge ring-TIH and tagged something at 8,950'- worked tool and continued in hole to 9,724'-could not get deeper-POOH&R/D ELine.,Moved wireline unit and laid out tb to be strapped-laid out bad jts and strapped 65 jts 3 1/2"L-80 9.2#SC-BTC tb that had previously been pull from this well=2,007.13'.,TIH w/singles to 2,007,13'-P/U hanger w/pup jt,total= 4.62'-landed hanger RILDS.tot footage=2011.75',NOS rep set BPV-N/D BOPE,Notice seals on hanger were cut- R/U landing jt and picked up hanger 3'- C/O seals and relanded hanger-ran in lock-down pins-tested hanger void to 500 psi low 5000 psi high. Presently testing tree. No FIW losses to well last 24 hrs Total losses f/job=1388 bbls FIW 6/11/2017 Pulled BPV and set 2-way check-shell tested dry hole tree to 500 psi low f/5 mins and 5000 psi high f/15 mins-good test. Handed well back to production at 0700 hrs.,Disconnected koomey,choke house,bang box and pump lines-moved equipment to clear skid path. Disconnected guy lines and scoped derrick down-R/U jacks to skid to 11-24 well. Stopped time on this AFE at 1300 hrs. • • Hilcorp Energy Company Composite Report Well Name: GPF GP 22-13RD3 Field: County/State: ,Alaska (LAT/LONG): ;Nation(RKB): API#: Spud Date: 8/17/2017 Job Name: 1711827D GP 22-13RD3 Drilling Contractor Kuukpik 5 AFE#: AFE$: 8/8/2017 Pre test BOP 250-3500PS1 Low-High,remove test joint and stand back same,continue to rig up top drive,install light in derrick,and replace tugger sheave secondary safety line.;Continue to prep for hanging service loop,while working on crane. Continue with welding.and painting projects.;Continue working on crane replacing seal in boom motor,Color code lines in sub,complete installation of secondary egress from rig floor to heliport,and review procedure to switch from rig power to;platform power. Tie in gas detection to platform system,and wire in remote accumulator panel into platform UPS system. String out service lines,measure and attach to bridle.;Move equipment and organize deck to receive multiple loads form work boat.Offload Top Drive service loops and drill pipe. Temporarily release work boat in order to hang Top Drive service Iines.;Uncrate and lay out large service lines(4 total).Install flanges in hanger bracket and make up loose fittings on hoses(came installed on hoses hand tight and without any thread compound).;Set saddle with small service lines on hanger bracket and secure. Hoist service loop into derrick and hang off.Install secondary safety restraint on service loops.;Adjust service loops and rehang in order to remove lines fout of the path of T.D.and out of collar finger access.Off load tubulars and mud products from work boat. 8/9/2017 Rearrange top drive service cables,due to excessive slack in service loop. Reposition anchor point for service loop bridal in derrick,connect service loop to top drive per NOV representative,;and assist electrician with running cables for top drive.;Continue to connect service loop to top drive,securing cables and lines clamps with safety wire. Loosen clamps on bridle,slipping service lines to even out same.;Continue slipping and evening out auxiliary service loop lines in bridle.Tighten clamps up and test run T.D.up through derrick checking clearances of service loops.Identified several potential;catch points that may require deflectors to be installed on mast.Transfer LVT to ISO on HAK deck.Offload mud products and misc equipment from work boat and backload boat with misc equipment.;PJSM,organize service lines in cable tray on bridge from dance floor to rig.Run service lines under dance floor,coil up on top of utility module and run through slots in dance floor to VFD and HPU.;Continue to run electrical service line under the dance floor,coil up on utility module and through slots in dance floor to VFD. Hang kelly hose in derrick and make up to T.D. 8/10/2017 Assist electrician running cables to NOV VFD,and HPU,terminating same. Test run top drive,trim guards on top drive to accommodate Kelly hose,tighten and secure same.;Commission top drive per NOV representative,install service loop guards,and function test BOP remote;Finish installing service loop guards, and commissioning T.D. Wire tie service loop bracket bolts,remove shipping brackets from T.D.dolly extend and function test same.Install bales and elevators,;and tighten up kelly hose.;Rig up to test BOP on 3-1/2"pipe.Fill system with water.;AOGCC representative Adam Earl on site to witness BOP test. Test annular to 250 psi/2500 psi,and test gas alarms.;Test upper rams to 250 psi,attempt to pressure up to 3500 psi on upper pipe rams experienced leaks on driller's side of both upper pipe and blind ram door seals,targeted tee on kill line,;LDS and graylock clamp at well head. Change out door seals on driller's side doors on upper pipe and blind rams.Tighten flange on target tee and run in packing on LDS.;Tighten graylock clamp with well head hand.;Test choke manifold valves,floor safety valves,upper and lower IBOP vales,kill and choke line valves,upper and lower pipe rams to 250 psi/3500 psi on 3-1/2"pipe.;Lay down 3-1/2"test joint and make up 4-1/2"test joint.Test blind rams(250/3500)while making up 4-1/2"test joint. Test annular on 4 1-2"pipe to 250/2500 psi.;Test upper and lower pipe rams to 250/3500 psi on 4-1/2"pipe,function test remote and manual chokes,perform accumulator drawdown test,200 PSI 20 second,full recovery 118 seconds 8/11/2017 Pull and lay down test joint,with left handed blank testing sub,remove 3"CIW BPV;Make up landing joint and screw into top of tubing hanger,pull same to floor,with 40K coming off hanger,removed tubing hanger,rigged up WOTCO tongs,performed a PJSM on laying down tubing.;Pull out of hole laying down 3 1/2"IBT from 2000'to 450';Continue to trip out of hole laying down 3.5"IBT from 450'to surface,and rig down WOTCO;Rig up Pollard E-line, run in hole with Baker 7"CIBP.set top of CIBP at 8514'.hag good indication of plug setting,picked up and set down to confirm set,pull out of hole and rigged down Pollard;Test casing to top of CIBP at 8514 to 2000 PSI for 30 minutes(Chart reading 2050 PSI at start and at 2025 PSI after 30 minutes.)(Had a 145 PSI increase in pressure on 13 3/8"x 9 5/8"annuls.);Run hoses for vacuum,Oil States crane mechanic replacing seal in main hoist motor. Screw into joint in slips hang block,conduct PJSM,slip 18 wraps of drilling line off drum.;Cont.working on Sea-Trax crane.Install hose clamp on rotary hose at top drive.Install hose clamp on shock hose in lower sub base.Rig up and test high pressure mud line to 4200 psi.Good test.;Rig up and RIH picking up 4-1/2"CDS-40 drill pipe. (Work on Sea-Trax crane suspended for the night©23:30);Continue to pick up and RIH with 4-1/2"CDS-40 drill pipe to 604';Add 3 drums of hydraulic fluid to rig HPU.;Continue to pick up and RIH with 4-1/2"CDS-40 drill pipe to 3546' 8/12/2017 Perform rig service,check fedder clamp bolts on draw works all good,draw works making noise;Continue to trip in hole picking up CDS-40 drill pipe from 3546 to 3671,noise getting worse.;Trouble shoot noise on draw works,change out DS hydraulic motor,inspect gear box slight amount of metal in bottom from break in of new gears.;Complete motor swap test run draw works up and down sounded good ran 4 joints of drill pipe and had same issue with noise.;Continue to trouble shoot draw works,while installing safety isolation retrofit kit,removed bell guide and 4 1/2"IF saver sub,attempt to install new CDS-40 saver sub,;found OD to be 1"too big on new saver sub,sent sub to town to have OD turned down,and change oil in HPU. Could not get signal from NOV VFD to Kuukpik PLC.;Remove long bails and elevators.Install CDS-40 saver sub on top drive.Change out gripper blocks and install bell guide for 4-1/2"drill pipe.Install 9'bails and elevators.;Continue to trip in hole picking up CDS-40 drill pipe from 3671'to 4657';Continue to trip in hole picking up CDS-40 drill pipe from 4657'to 5894'.;Unable to start Link Belt crane to load pipe in V-door,changed out starter on crane,rotate stand pipe 1/8th turn and organize storage area under HAK deck while waiting on crane repairs.;Continue to trip in hole picking up CDS-40 drill pipe from 5894'to 6486'. • 8/13/2017 Continue to pick up and run in hole with drill pipe from 6641'tagging top of CIBP at 8513'DPM,(8514'WLM).;Stand back stand,had to adjust top drive for standing back pipe,Pipe is riding back side of table,prep to level the derrick and adjust T-bar on top drive rail.;Level derrick,adjust T-bar to center over well, NOV representative calibrated counter balance/stand jump setting on top drive,change out drill pipe elevators.;Trip out of hole from 8466'to 67'leaving 1 stand in the hole.;Service top drive,blocks and drawworks.;Make up top drive into stump in rotary table and hang blocks in derrick.Spool drilling line off of drawworks drum.;Measure deflection and end play on both ends of drawworks shaft and gearboxes-NONE. (Sea Trak crane put back in service at 01:00);Remove drawworks motors and gear box from ODS side.Inspect and change out seals.;Wellhead pressures:20"=31 psi,13 3/8"=38 psi Fluid loss to well today:0.0 bbls. Total:0.0 bbls. Code 8 today: 6.0 hrs, Total: 12.0 hrs. Metal recovered today: 0.0 lbs. Total:0.0 lbs 8/14/2017 Continue to work on draw works ODS gearbox,check for end play,adjust bearing thrust,removed a shim where seal seated reinstall gear box with new seals, and hydraulic motor,;hook up hoses and test run same. Checked for noise,heat and vibration,appeared to be good. Plan to check again with a load. Drain DS gear box and pull encoder plate inspected bolt all good.;Drilling line that was removed from drum earlier appeared to be deformed,it was cut off and new line slipped on.;Stage equipment and pick up Baker whip stock,anchor pined with 4 screws with a shear value of 13000#,connected to window mill with a 35K shear bolt,complete with upper and lower watermelon mills,;picked up Sperry MWD and scribed same,continue picking up 8 drill collars and 18 joints of HWDP.;Trip in the hole with Whipstock BHA to 1573'(Shallow hole test MWD 295 gpm=770 psi at 958');Change out bails and adjust link tilt.;Continue tripping in hole with Whipstock BHA to 3376';Service drawworks,top drive,blocks and crown;Continue tripping in hole with Whipstock BHA to 8465'.;Orient Whipstock to 45°right of high side as per directional driller and Baker rep,Set down @ 8513'and shear anchor with 8k down wt. Pull up to 5k over,shear pin on Whipstock with 26k down weight.;Clean pits for receiving OBM to displace well with.;Wellhead pressures:20"=31 psi, 13 3/8"=38 psi Fluid loss to well today:0.0 bbls. Total:0.0 bbls. Code 8 today: 6.0 hrs, Total:18.0 hrs. Metal recovered today: 0.0 lbs. Total:0.0 lbs 8/15/2017 Clean and prep pits,for OBM displacement, draining water to production,build spacer,hook ISO tanks to drain to pits,and repair mud trough over pit 5.;PJSM,transfer mud from platform beam tank to pits.Reseal 2 pumps on HPU#2.Install drip pan on back of shakers in cellar.;Hold PJSM.Build spacer in pill pit and displace well to OBM at 3 BPM/480 psi taking returns to production.;Circulate OBM back to pits.Bring on volume from ISO tanks.Circulate and conditon mud @ 6 bpm 1500 psi.;Pick up single of drill pipe.Establish paramaters UP=132,DN=120,ROT=121,90RPM,TQ=3.5K.TOW @ 8495',300 GPM=2000PSI;HPU#2 blew off radiator hose.Reattach hose and add glycol to radiator.;Mill window per Baker Oil Tool from 8495'to 8496'with 300 GPM, 1900 PSI,90 RPM,3.5K TQ,0.5 WOB.;Repalce leaking o-ring on HPU#1.;Mill window per Baker Oil Tool from 8496'to 8508'with 300 GPM,1900 PSI,90 RPM,3.5-7K TQ,0.5-5.5K WOB.(MW IN 8.9/VIS 96,MW OUT 9.2/VIS 93);Mill formation from 8508'to 8528'with 281 GPM, 1780 PSI,90 RPM,4-5K TQ,7-8K WOB.(MW IN 8.9/VIS 83,MW OUT 8.9/VIS 75)Ream through window 5,pick up through window W/O ROT-No Issues;Circulate and condition bottoms up for FIT.;Wellhead pressures:20"=28 psi,13 3/8"=30 psi Fluid loss to well today:0.0 bbls. Total:0.0 bbls. Code 8 today: 1.5 hrs, Total: 19.5 hrs. Metal recovered today: 120 lbs. Total:120 lbs .,of Tq g ��\�y/,'s. THE STATE Alaska Oil and Gas F �, of/0 T nn '' //A� Conservation CommissionSr£ �� 333 West Seventh Avenue '11._.: '. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF L.9 Fax: 907.276.7542 www.aogcc.alaska.gov Stan Golis Operations Manager s, . � <<,A., ' . r._. � Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Granite Point Field, Middle Kenai Oil Pool, Granite Pt St 22-13RD2 Permit to Drill Number: 196-075 Sundry Number: 317-163 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, /"' 1SL Cathy P Foerster Chair DATED this 24day of May, 2017. RDDMMS t,L MAY - 3 2017 0 • RECEIVED STATE OF ALASKA AVR 2 4 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon El Plug Perforations❑ Fracture Stimulate El Repair Well El Operations shutdown El Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill 0- Perforate New Pool El Re-enter Susp Well ❑ Alter Casing El Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC ' Exploratory ❑ Development ❑ 196-075 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service 0 , 6.API Number. Anchorage,AK 99503 50-733-20095-02 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 El No 0 ,/ Granite Pt St 22-13RD2 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): ' 13,934 10,811 ' 11,142 ' 9,752 ' 1,576 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural 294' 26" 294' 294' Conductor 600' 18" 600' 598' Surface 3,989' 13-3/8" 3,989' 3,973' 3,090 psi 1,540 psi Intermediate 6,643' 9-5/8" 6,643' 6,616' 5,750 psi 3,090 psi Production 5,017' 7" 11,377' 9,907' 6,160 psi 7,020 psi Liner 2,707' 4-1/2" 13,922' 10,808' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10,534-11,650 ' 9,351 -10,055 3-1/2" 9.2#/L-80 10,332 2-7/8" 6.5#/L-80 10,420 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): SC-1R Pkr,FA-1 Pkr,SC-2P Pkr 4,935'(MD)4,917'(TVD),6,499'(MD)6,473'(TVD),10,322'(MD)9,218'(TVD) 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development❑ Service 0 14. Estimated Date for 15.Well Status after proposed work Commencing Operations: 5/10/2017 OIL ❑ WINJ El WDSPL ❑ Suspended El - 16.Verbal Approval: Date: GAS ❑ WAG El 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: dmarlowec ihilcorp.com G4� l Contact Phone: (907)283-1329 Authorized Signature: ✓ t� r .. Date: ' (v1 2,p/'J COMMISSION USE ONLY Conditions of approval: Notify Commission{{so that a representative may witness Sundry Number 1 31-7—k<R3 Plug Integrity ❑ BOP Test[�[I Mechanical Integrity Test ❑ Location Clearance El (-K-s- 6 11-l CI- Other: -Other: 35' 0 p— J6 49, 4 Alf Pl, 10/A.,....4- pp.^,,J e Zo ,4* z 5. //2_ (<) Post Initial Injection MIT Req'd? Yes El No ❑ p r Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: 10 '^`i 0 7- RBDMS Lu_ MAIv - 3 2617 APPROVED BY Approved by: aee,firCOMMISSIONER THE COMMISSION Date:,$. Z — / 7 grill2s/17-- %ern 7e s=(-i 7- 0gplOSubmit' .. Form ane Form 10-403 Revised 4/2017 �j.31IltAiI ,aIid for 12 months from the date of approval. Attachments in Duplicate • • II Well Work Prognosis Well: GP 22-13rd2 Hilcorp Alaska,LLC Date: 04/07/2017 Well Name: GRANITE PT ST#22- API Number: 50-733-200095-02 13RD2 (GP 22-13rd2) Current Status: Shut-In Injector Leg: Leg#3 Estimated Start Date: May 10, 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: 196-075 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: 2,511 psi @ 9,351'TVD 0.269 lbs/ft(5.16 ppg)based on SIBHP Maximum Expected BHP: 2,511 psi @ 9,351'TVD 0.269 lbs/ft(5.16 ppg)based on SIBHP Maximum Potential Surface Pressure: 1,576 psi Using 0.1 psi/ft gradient per 20AAC25.280(b)(4) Brief Well Summary GP-22-13rd2 is a shut-in C sands injector last worked over in Septemb 1997. This workover will plug back the existing completion and prepare the well to sidetrack into th C- Last Casing Test: 7 N/A L 1`.'- `/4) /..,i3,—,— I- ,_-_----- Procedure: ci Phase I 1. MIRU Moncla 404 2. RU e-line and RIH to+/-10,325' and punch tubing. Work over fluid will be FIW. BOP's will be closed as needed to circulate the well. 3. 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). 4. Monitor well to ensure it is static. 5. Attempt to un-sting seals. If no go, RU e-line and RIH to±10,325' and cut tubing. 6. Unseat hanger and POOH with completion. • 7. RIH with bit and scraper to±4,935', circulate clean. POOH. i k 45,-; .,.....„.143 8. Fish and Recover Straddle Packer Assembly from 4,935'—6,499'. F....5/.. S% )' x 9. RIH with bit and scraper to±9,000', circulate clean. POOH. 10. RIH with work-string and spot a >100' balanced cement plug on top of the injection packer at to ±10,330'. (well will not take injection fluid) 11. POOH w/work-string 1tc .c 12. RIH with RTTS to±8,500 anti Pressure Test plug back to 2,500 psig for 30 minutes and chart. 13. POOH w/work-string ,i'z��.,� ��---- 14. RU e-line and RIH w/CIBP to ±8,500', ±5' above casing connection. POOH Lee;,t-. tey._ 15. RIH with ±2,000' of kill string r7 16. Set BPV, ND BOP, NU Dry Hole Tree and test. 17. Suspend operations Well Work Prognosis Well: GP 22-13rd2 Hilcorp Alaska,LLC Date: 04/07/2017 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. 6. Circulate well and pull kill string 7. PU whipstock and mills and RIH to CIBP. 8. Orient and set whipstock in 9-5/8". 9. Swap well to OBM drilling fluid. 10. Mill 6" window and 20' of new formation. POOH and LD mills. ***Remaining Procedure to be included on new PTD*** General sequence of operations pertaining to drilling procedure:(informational only} 1. PU directional BHA and TIH to window. 2. Drill 6" hole to the C-7 sands. 3. Run/Cement/and cleanout 5" casing. 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 • Granell:iteGranite Point Platform WPt St 22-13RD2 Last Completed:09/08/1997 SCHEMATIC PTD: 196-075 API: 50-733-20095-02 Hilcorp Alaska,LLC KB=42.3'or115'RlBfrom MSL CASING DETAIL Size Wt Grade Conn ID Top Btm 26" Inside Conductor Surf 294' 26" 18" 70.59 B Surf 600' 13-3/8" 61 J-55 BTC 12.515" Surf 3,989' 9-5/8" 40&43.5 N-80 Butt&8rnd Surf 6,643'TOW 7" 29 L-80 BTC 6.184" 6,360' 11,377'3,922' 4-1/2" 12.6 L-80 SC-BTC 3.958" 11,215' 1 " L L (slotted) 18 TUBING DETAIL 3-1/2" 9.2 L-80 SC-BTC 2.992" Surf 10,332' 2-7/8" 6.5 L-80 BTC 2.441" 10,354' 10,420' 13-3/8" 1 1 4 JEWELRY DETAIL No Depth Depth ID OD Item ,�35 (MD) (ND) �` 1 10,332' 9,218' 2.437" 3.500" Baker Locator and 80-32 Seal Assy(16.65') r 2 10,333' 9,219' 3.250" 5.820" 7"Baker SC-2P Retrievable Packer Ad' 9-s A-F 7 f. 1 Taw 3 10,338' 9,222' 3.250" 5.460" 80-32 Seal-bore Extension(15.75') Ay tevo.• 4 10,386' 9,253' 2.313" X-Nipple 16 5 10,420' 9,275' 2.441" 3.500" Wireline Re-entry Guide 4413' row ,.{s Straddle Packer Assembly A 4,935' 4,917' 6.000" 8.406" 9-5/8"x 7"Baker SC-1R Retrievable Packer B 4,940' 4,922' 6.593" 7.625" Mill-out Extension(5.85') C 4,946' 4,928' 6.151" 7.000" 7"29#L-80 Buttress Casing(4,946-6,260) D 6,261' 6,236' 4.283" 5.000" 5"15#L-80 Buttress Casing(6,261-6,489) E 6,499' 6,473' 4.000" 5.600" K-Anchor F 6,499' 6,473' 4.000" 5.875" Baker FA-17"x5"Permanent Packer w/85- 40 blank bottom �_ _� to333 ,1 -► 1,2 m- 3 PERFORATION DETAIL ®' 4 Zone Top Btm Top Btm FT Date Status Comment __5 (MD) (MD) (ND) (TVD) rC2Sxd C2 10,534' 10,602' 9,351' 9,396' 68' 10/11/1996 Open 2-1/8"EJ C5 11,490' 11,530' 9,976' 9,997' 40' 5/28/1996 Open 2-1/8"H.C. C5 11,550' 11,570' 10,007' 10,017' 20' 5/28/1996 Open 2-1/8"H.C. lfC5 11,610' 11,650' 10,037' _10,055' 40' 5/28/1996 Open 2-1/8"H.C. Sand C 7 Notes: - I GR/CCL ran in 12/97 shows tbg tail NOT present J 10/11/2000—Tagged fill at 11,142'(WLM) 41/2" PBTD:777' TD:13,934' MAX HOLE ANGLE=83° Updated By:JLL 03/17/17 GraniteGranite Point PlatformPtSt Last Completed: Future H 0 PROPOSED • Well:PTD: 196-075 API: 50-733-20095-02 Hilcorp Alaska,LLC IB=42.3'or 115'RlBfrom MSL CASING DETAIL Size Wt Grade Conn ID Top Btm z6' l 26" Inside Conductor Surf 294' 18" 70.59 B Surf 600' 13-3/8" 61 J-55 BTC 12.515" Surf 3,989' 9-5/8" 40&43.5 N-80 BTC&8rnd Surf 6,643'TOW 18" 7" 29 L-80 BTC 6.184" 6,360' ±8,500'(KOP) 4-1/2" 12.6 L-80 SC-BTC 3.958" 11,215' 13,922' (slotted) 13-3/8" TUBING DETAIL 1 3-1/2" 9.2 L-80 SC-BTC 2.992" ±10,325' 10,332' 2-7/8" 6.5 L-80 BTC 2.441" 10,354' 10,420' JEWELRY DETAIL No Depth Depth ID OD Item (MD) (TVD) ss/a° r 1.0•0'- ±8,500' ±8,148' CIBP(set for whipstock) I 1 10,332' 9,218' 2.437" 3.500" Baker Locator and 80-32 Seal Assy(16.65') 2 10,333' 9,219' 3.250" 5.820" 7"Baker SC-2P Retrievable Packer 3 10,338' 9,222' 3.250" 5.460" 80-32 Seal-bore Extension(15.75') 4 10,386' 9,253' 2.313" Otis X-Nipple r 5 10,420' 9,275' 2.441" 3.500" Wireline Re-entry Guide II/12' A$ tF PERFORATION DETAIL V- TOC@<10,225' Zone Top Btm Top Btm FT Date Status Comment (MD) (MD) (TVD) (TVD) C2 10,534' 10,602' 9,351' 9,396' 68' 10/11/1996 Open 24/8"EJ ,1,:i:, 'r t . { C5 11,490' 11,530' 9,976' 9,997' 40' 5/28/1996 Open 2-1/8"H.C. ® ®- 1 2 CS 11,550' 11,570' 10,007 10,017 20' 5/28/1996 Open 2.1/8"H.C. 3 C5 11,610' 11,650' 10,037' 10,055' 40' 5/28/1996 Open 2-1/8"H.C. El 4 5 C2 Sand A 6 + 7 n'^ Notes: V� x GR/CCL ran in 12/97 shows tbg tail NOT present > kc sand 10/11/2000—Tagged fill at 11,142'(WLM) tC M 4-1/2" rigaiWitaffl PH I U:???' TD:13,934' MAX HOLE ANGLE=830 Updated By:1LL 03/17/17 • • II Granite Point GPP 22-13RD2 03/27/2017 Granite Point GPP 22-13RD2 Tubing hanger,FMC-UH- 18 X 13 3/8 X 9 5/8 X TC-1A-EN,13 5/8 5M X 3''A 3 1/2 IBT lift and 3''A IBT susp,w/ 3"type IS BPV,6.990"EN BHTA,OCT-B-11-AO, 3 1/16 10M FE Fif 3Te'".` gni Valve,Swab,FIP, C 3 1/16 10M FE,HWO, s• 6, BB trim 1.:1 Valve,Wing,FIP, 1r°-ri!1° 3 1/16 10M FE,HWO, BB trim La11 IIIil1 i t Valve,Master,FIP, -' 3 1/16 10M FE,HWO, • 4,75- BB 4BB trim _ ° �;' k k®k @®SL- Valve,Master,WKM-M1, <•. 3 1/16 10M FE,HWO, G'� BB trim ,,. —Iliad Adapter,FMC-ASP,135/85M 64566? API clamp X 3 1/16 10M,w/ 6.990"extended neck pocket Unihead,OCT type 2,13 5/8 5M API hub top X 13 3/8 BTC casing bottom, f'< ';} w/2-2"LPO on lower section,2-2 1/16 5M SSO on upper section,IP ■internal lockpin assy 1 , _ Valve,OCT-20,2 1/16 5M '0) o '1 • 'ryPn ,1 11 HWO,AAtrim I wi ,1 rte. .t Starting head,OCT, a I 'k J' "1" 21 1/4 2M Hub x 24''41M I _ ' Va Ive,OCT-20,2"LPO,HWO, in, Hub w/2-2"LPO,prepped f/ . AA trim 18"EN hanger I �_1_ `i *:+14"5-1- . Conductor housing, i I 24'/.1M Hub X El 6 24"Buttweld II L 18" __113 3/8" 9 5/8" 3''4" 0 • Ili Granite Point Platform Moncla BOP nitrurp:11usko,1.IA: Ill 11I'111aat._ asa Hydril 0 k GK 13 5/8-5000 NIIIP NMI iii iii ill ill iii gilt ill iil 1U 1(I I!I IF _—ire CIW-U �— Variable rams '.- 2 7/8-5 4.67' 13 5/8-5000 Jla Blind Rams n`1ft1ffi11 nt Choke and Kill valves 21/165M lam. ;,1[PI PIl19f1'Itl � _ � ; € 2.26' z511110 / .�1 -1. 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U) W a 1—II L_J� ET_ a z 1— U) z C 0 P Zw aDz CCI Q 411J U)H __ 2a A 2CODO Z Z `torYOCDH d- O � zQ *kaQu» O DWUC) • CL Z N Q pp � `U ' a CI Z � QOc� C p D 2 D o • D O w r u)LU a JOZw KJ,77 Ln aN LL Z � C o Q m z Q ° I- J a D ULJi Ct IP. M t► 0 S I Moncla Rig 404 BOP Test Procedure Hilcorp Aliska,LL( 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.) i 1 Moncla Rig 404 BOP Test Procedure H;,,�,r,,Alaska,LLC Attachment#1 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 15t 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 ft 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. • Moncla Rig 404 BOP Test Procedure Hilcorp Alaska,1,1kAttachment#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. 1110 •Granite Point Platform 2017 BOP Stack(Kuukpik) 04/24/2017 Hilairp Alaska_1.1A. Rig Floor .i0• 111 Aammii. 111 16" Pipe lit tit drdrib t - irti cTh rf ftrfi 3.74' Shaffer 13 5/8 5M d Shaffer SL R i.�} � 2 7/8-S.S Variables 2'83 `! 13 5/8 SM zif -1i�r Blind A 2 1/16 5M manual and HCR valv 2 1/36 5M manual and HCR valve t!l 111 111 1/1 1.76 ' � { }ice , - ? At. lit illIiElil�lit 1.44' Shaffer SL al4W 135 8IliUg 2 7/8-5.5 Variables LULUS Drill deck 13.70' Riser 13 5/8 5M FE X 13 5/8 5M API hub • I Choke Manifold Valves 2 " 3" To Shaker 3" Panic To Gasbuster 3 1/8"u 2 1/16" ----.....n_l O 2 /1 16" i, ,c-?,___ _iriii _ , EL + 21/16" (: ) 2 1/16" t-., _ 3 1/8" 8 O ��O A N Le MONO IIR I 0 J 1 21/16" - 2 1/16" Manual Choke - Automatic Choke 2 1/16" Inlet Pressure Sensor 3" 5,000 PSI Choke Manifold Kuukpik Drilling Rig 5 RED = 3 1/18" 5,000 PSI VALVES AND LINES BLUE = 2 1/16" 5,000 PSI VALVES Kuukpik Drilling Rig 5 Choke Manifold C #t1 #10 1.*.-- d #9 4 -*"..L �e Z #16 #5 14 #1 #2 it #4 _ IIIL C-1 #15 Kuukpik Drilling Rig 5 Choke Manifold • i E czt g oi7i oi7ci o '7,! of of _ ,. v; O! O�N O! k0 �!v1 iL,1 ° U10j.01 O a• r 1 I 1 1 .--, ql I °la I I I w - - '.--1 ',mi.,' yl I I O w G al Iy°IQl ql l • w - a , �i 1.—Cat a•it _ O ,+-' ® D- d11 1—I"I .p1 nl l 0 �i � AiqaiaV11w+ c0o o_ II r 1x1 '01 c11,••• 01 or.-o E. 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In � -I_.I-I.�I...1...1....4....1..........1...,-I,ISI NIell rill etININININIrill ,bEl U_ y 111111111 W s -,k4kovis11`°1r`101ai f>3 = II ii ii 1 I 1 bA d i . .0 .,--, M ^^ p • • t 1 1 1 1 I 1 I y aI yl yl NIS NI al al tt• '. =101 C10IC 0101 a1 .. 0. I 1 IUIN UI 1 1 Q y1 I I al I I C) AI 1 a1=A'1 I I - ^� _ ;"1 1.41i1 a 1 +I 01 1 ,11 %1 m1711 ; Kuukpik 5 BOP Test Procedure Hilrnrp Alaska,LLCAttachment#1 Attachment #1 Hilcorp Alaska LLC. 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 r{.�, rr 11, ka ( 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 • • = m °' d > ca a) > W o0 C CU o °' vim a s 0 o= y VU aaa E E E co 13 U = d N • E Q LO m:7 F. O 2 Q _ >, E Q L •- -0 a) � a6i Yd w ea >Jo > 2 d m aJ i E ti OL 'L d v O Q" c 0 (0 co 2 r al (4 M -0 12 r D O iZ ClCl CC I— a CD a) =10-%_ C O Z W CI RS W _C L ch U o a N° `° CD N _0 ° �0a � Q a = 0_ a) a) ` oco L C) 3 co a — y co U -10 0 112 co � O o CQm • CD °' E ` 0 O 0 = O v - •m d a.) n. 3 U c at a)C i (C = .9 = 2 .0) N -a N 0 C W � a wo > a) co o U 0. L Cu m +-� 0 Q > CI O L. cei ,�Ct ° al ai o E 0. X o co d x O H To C.)o 0 d CuX Cu A' CO .0 x ° a ii ° e-, w �t UCt) ii ..~i �► 0 U n. 2 x o -a E0 o cu c� CL • • Schwartz, Guy L (DOA) From: Dan Marlowe <dmarlowe@hilcorp.com> Sent: Thursday,April 27, 2017 3:56 PM To: Schwartz,Guy L(DOA) Cc: Bettis, Patricia K(DOA); Monty Myers Subject: RE: PLug for Redrill on GPS 22-13RD2 (PTD 196-075) Guy This is exactly why we want to get the Moncla 404 on the well for the decomplete prior to mobilizing the Kuukpik#5 This allows us to remove the current scab liner and evaluate what we are dealing with. Between steps 13 & 14 we will conduct a casing inspection which could include a caliper and RTTS for diagnostics. Depending on what we find we will have to make a plan which would likely be implemented when the Kuukpik#5 arrives. Without knowing what it looks like, I can think of a few different options • Leave as is if minor leak and we can pass the FIT • Squeeze the leak if moderate and casing is reasonably intact—cover with liner during completion • Install a 7" or 7-5/8" liner from the current 7" liner top to surface if just the 9-5/8 casing is in bad shape After drilling the sidetrack we intend to run a 5" semi-flush liner in the well which will cover any damage in the 7" and tie in either in new upper liner or high enough to cover any damage in the 9-5/8" Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Fax 907-283-1315 Email DMarlowehilcorp.com Hilcorp A Company Built on Energy From:Schwartz,Guy L(DOA) [mailto:guy.schwartz@alaska.govj Sent:Thursday,April 27,2017 2:42 PM To: Dan Marlowe<dmarlowe@hilcorp.com> Cc: Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov> Subject: PLug for Redrill on GPS 22-13RD2(PTD 196-075) Dan, I see you are pulling the liner lap (7"x 9-5/8")straddle packer as part of prep for the Sidetrack. What is the nature of the leak...will you be able to get an acceptable FIT for the drilling portion with this open? Do you plan to re install ?? etc. Guy Schwartz Sr. Petroleum Engineer AOGCC 1 A 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 "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 ) 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. Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. - They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by; Bevedy Vincent Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent ~n Lowell • • Chevron Steve Lambert Union OiI Company of California Reservoir Engineer P.O. Box 196247 Anchorage, , AK AK 99519 -6247 Tel 907 263 7658 Fax 907 263 78484 7 Email salambert @chevron.com October 19, 2005 Alaska L, Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 4°r trs r;, 333 W. 7th Ave # 100 Anchorage, Alaska 99501 -3539 CONTINUATION OF INJECTION WELL SHUT -IN GRANITE POINT FIELD WELL NO. 22 -13RD2 PERMIT NO. 196 -075 GRANITE POINT PLATFORM GRANITE POINT FIELD APR �� t l R. N Dear Tom: Per the attached Assessment of Well Utility, for Granite Point Well No. 22 -13RD2 (Permit No. 196 -075), Granite Point Field, Chevron submits the following information to demonstrate the stability of the downhole fluids in the wellbore. Well No. GP 22 -13RD2 is an injector which was shut -in in October 2000 due to a failed MIT. The attached temperature surveys from 8/29/04 and 6/29/05 nearly overlay each other on identical temperature gradients indicating no movement of the downhole fluids. Chevron requests that the AOGCC, upon agreement with the temperature survey analysis, sign and date the concurrence line below. Please fax a signed copy to Unocal (fax 263- 7847). Chevron will continue to monitor and record daily tubing and casing pressures on the well and provide a report to the AOGCC on a monthly basis. A temperature survey will be run every two years to determine the stability of the fluids in the wellbore. Please call me at (907)263 -7658 if you have any questions. Best regards, Steve Lambert cc: Bob Fleckenstein Attachments Concurrence: Date: Union OiI Company of California / A Chevron Company http: / /www.chevron.com STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION 2005 REPORT OF SUNDRY WELL OPERATIONS ��� Alaska Oil & Gas Cons. Commission 1. Operations Abandon L Repair Well LJ Plug Perforations Li Stimulate I_ Other [ In titre Shut -In Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator Union Oil Company of California (Unocal) 4. Current Well Class: 5. Permit to Drill Number: Name: Development ❑ Exploratory 196 -075 3. Address: P.O. Box 196247 Anchorage, AK 99519 Stratigraphic Service 0 6. API Number: 50- 733 - 20095 -02 7. KB Elevation (ft): 9. Well Name and Number: 115' GPP 22 -13 RD2 8. Property Designation: 10. Field /Pool(s): Granite Pt Field / Granite Point Platform Granite Pt Field/Tyonek 11. Present Well Condition Summary: Total Depth measured 13934 feet Plugs (measured) true vertical 10811 feet Junk (measured) Effective Depth measured 11135 feet true vertical 9740 feet Casing Length Size MD TVD Burst Collapse Structural 247 26 294 294 Conductor 553 18 600 600 Surface 3942 13 3/8 3989 3975 Intermediate 6596 9 5/8 6643 6616 Production 5017 7 11377 9906 Liner 2707 41/2 11215 -13922 10799 Perforation depth: Measured depth: various 10534 - 11650 True Vertical depth: various 9348 - 10058 Tubing: (size, grade, and measured depth) 3 1/2 - -- 2 7/8 9.2# L -80 / 6.5# L -80 10354 / 10354 - 10420 Packers and SSSV (type and measured depth) B.O.T. SC-1R pkr @ 4935', B.O.T. FA -1 pkr @ 6499', B.O.T. SC -2P pkr @ 10,332' Camco SCSSV @ 323'. 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: no water injection Subsequent to operation: no water injection 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Temp Survey Exploratory Development ❑ Service El Daily Report of Well Operations 16. Well Status after proposed work: Oil❑ Gas El WAG ❑ GINJ ❑ WINJ El WDSPL ❑ 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: Contact Steve Lambert 263 -7658 Printed Name Steve Lambert Title Reservoir Engineer Signature Phone 263 -76RBDjS BFL 0 CT 2 0 ?0055 Date 10/20/2005 ..._ Form 10 -404 Revised 04/2004 O Submit Original Only y • Unocal Alaska Resources • Unocal Corporation 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519 -6247 Telephone (907) 276 -7600 UNOCAL 7v Steve Lambert Reservoir Engineer September 6, 2005 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501 -3539 ASSESSMENT OF WELL UTILITY GRANITE POINT FIELD WELL NO. 22-13RD2 PERMIT NO. 196-075 SUNDRY APPROVAL NO. 302-400 GRANITE POINT PLATFORM GRANITE POINT FIELD Dear Tom: ' In response to a request by the AOGCC on a Sundry Approval (No. 302 -400) for Granite Point Well No. 22 -13RD2 (Permit No. 196 -075), Granite Point Field, Chevron submits the following information concerning an action plan for this well. Well No. GP 22- 13RD2, an injector which was shut -in in October 2000 due to a failed MIT, is being retained for potential future utility as an injector. Please note that this information has been reported to the AOGCC (Mr. Jack Hartz) yearly on an annual shut -in well report. However, in the event that this report is not sufficient as a response to the sundry or has not been reaching you, we are additionally notifying you through this submittal. Attached for informational purposes are copies of the annual shut -in reports for 2002, 2003, and 2004 mentioned above, a copy of the sundry, and a schematic. Chevron will monitor and record daily injection rates and tubing and casing pressures on the well and provide a report to the AOGCC on a monthly basis. A temperature survey will be run every two years to insure that fluids continue to be contained within the completion interval. Please call me at (907)263 -7658 if you have any questions. Sincerely, t tiv X,cxi Steve Lambert JHM:jII Attachments O: \OOE \OOEFields \GPF\Granite Point \Wells \Gp 22 -13 \Gp 22- 13RD2Inj\State_Forms \Correspondence \GP 22 -13RD2 Sundry Response Sep05.doc • ! • 'Unocal I WeII:IGPP 22 -13RD2 I Field:IGranite Point Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 0 i I Pressure Temperature Profile 1. Going in hole 1000 2. Shut - In 2000 3000 4000 CD 5000 CS • 6000 Q ▪ 7000 8000 9000 10000 11000 12000 I I 50 60 70 80 90 100 110 120 130 140 150 160 170 Temperature (Deg. F) —6-29-05 Pressure — Perfs 13 3/8" —9 5/8" 7" —TBG —8-29-04 Temp —6-29-05 Temp • • 'Unocal I WeII:IGPP 22 -13RD2 I Field:IGranite Point I I i Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 0 I I i 1 Pressure - Temperature Profile 1. RIH Hole to 9658' TVD 2. Shut - In 1000 — 2000 3000 4000 _ G> - C 6 - > 5000 H - CP - , 13 6000 • 7000 8000 9000 10 10000 i I I i i I I I 1 I 50 60 70 80 90 100 110 120 130 140 150 160 170 Temperature (Deg. F) — 6-29-05 Pressure — Perfs 13 3/8" — 9 5/8" 7" —TBG —8-29-04 Temp —6-29-05 Temp * ` a K. GRANITE POO' PLATFORM ALASKA DRILLING WELL # 22 -13 RD #2 WATER INJECTOR UNOCAL 76 FINAL COMPLETION: 9/8/97 KB = 42.3' or 115' RKB from MSL CASING AND TUBING DETAIL L , SIZE WT GRADE CONN TOP BOTTOM 26" Inside Conductor 47 294 18" 47 600 13 -3/8" 61 J -55 47 3,989 9 -5/8" 40 -43.5 N -80 47 9417 Window Cut in 9 -5/8" 6,643 6,670 Z. 7" 29 L -80 BTC 6,360 11,377 4 -1/2" 12.6 L -80 (Slotted) SC -BTC 11,215 13,922 Tubing 3 -1/2" 9.2 L -80 SC -BTC 43.15 10,354 z. g A 2 -7/8" 6.5 L -80 BTC 10,354 10,420 B s C .., JEWELRY DETAIL b E NO. DEPTH ITEM G 1 10,325' Baker Locator , and 80 -32 Seal Assy (16.65') 2 10,332' 7" Baker SC -2P Retrievable Packer 3 10,325 80 -32 Seal -bore Extension (15.75') 4 10,386 X- Nipple (ID = 2.313 ") 5 10,420 Wireline Re -entry Guide 3 Straddle Packer Assembly /I/ 1,2 A 4,935 9 -5/8 "x 7" Baker SC -1R Retrievable Packer 3 B 4,940 Mill -out extension (5.85') 4 C 4,946 -6,260 7" 29# L -80 Buttress Casing gil 5 D 6,261 -6,489 5" 15 # L -80 Buttress Casing E 6,499 K- Anchor a I G 6,499 Baker FA -1 7 "x 5" Permanent Packer with 85 -40 blank bottom GR/CCL ran in 12/97 shows tbg tail NOT present II C-5 SAND I I V I I I PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 10,534 10,602 C -2 6 10/11/96 2 -1/8" EJ z ( 11,490 11,530 C -5 4 5/28/96 2 -1/8" H.C. TD = 13,821' 11,550 11,570 C -5 4 5/28/96 2 -1/8" H.C. MAX HOLE ANGLE = 83° 11,610 11,650 C -5 4 5/28/96 2 -1/8" H.C. GP 22 -13RD2 Final 9- 8- 97.doc DRAWN BY: MWD 9/18/97 Revised 2/29/99 ) Unocal Alaska Resourcl ) Unocal Corporation 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCALe " If..... 0"",,, ~.~::~'~:CEí\l t:. ~' ,~ '\. '""".. 'I..P (~ Steve Lambert Reservoir Engineer September 6, 2005 .' ''''''''''1...011... .' ." (\ j I? Ga> GO;1i. O,)fI·~m~~:£-kT! 1\j~t~ \{...! ~ ,~~'~'};V"~~\J(.~ ~~ T '. r \" I . ~'vrc.. 'L~:~ \)'1.) ìÌ'.~~"\-'O""" ~y .'-:7 .} ~ ~.' ~".."'7~~~'" "Q~~~~C~ '-£.) N.-~.\ . C V'l) ð~ .\0 ìå:-'õ~.5;~. ~~\ \cs» CJ,,-'a V r !R- Qtf)G. ( 1'1 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 ASSESSMENT OF WELL UTILITY GRANITE POINT FIELD WELL NO. 22-13RD2 ì> PERMIT NO. 196-075 SUNDRY APPROVAL NO. 302-400 GRANITE POINT PLATFORM GRANITE POINT FIELD ';sr I' ~~~b\.UfEK"; t:_.~~~ ~:¡;4'11 Jttj \, ~ '.!! ....;.~JL.;- )i) ~I- ~ ¡:'. (2'. (1 [p....:. 1 ..;;)) :. " ),1) Dear Tom: In response to a request by the AOGCC on a Sundry Approval (No. 302-400) for Granite Point Well No. 22-13RD2 (Permit No. 196-075), Granite Point Field, Chevron submits the following information concerning an action plan for this well. Well No. GP 22-13RD2, an injector which was shut-in in October 2000 due to a failed MIT, is being retained for potential future utility as an injector. Please note that this information has been reported to the AOGCC (Mr. Jack Hartz) yearly on an annual shut-in well report. However, in the event that this report is not sufficient as a response to the sundry or has not been reaching you, we are additionally notifying you through this submittal. Attached for informational purposes are copies of the annual shut-in reports for 2002, 2003, and 2004 mentioned above, a copy of the sundry, and a schematic. Chevron will monitor and record daily injection rates and tubing and casing pressures on the well and provide a report to the AOGCC on a monthly basis. A temperature survey will be run every two years to insure that fluids continue to be contained within the completion interval. Please call me at (907)263-7658 if you have any questions. ;:~ X~ - Steve Lam bert JHM:jll Attachments O:\OOE\OOEFields\GPF\Granite Point\Wells\Gp 22-13\Gp 22-13RD2Inj\State_Forms\Correspondence\GP 22-13RD2 Sundry Response Sep05.doc UNION OIL COMPANY OPERATED PROPERTIES WELL DATA FIELD MtöÖØ;';1Rlj~~«. ,J111¡""IlW SUMMARY SöJ1tä.1tfiDÐØ;ORö~~D"'Ü ~~LMIW SUMMARY ~Pò~xþø;ï316.~,t~ SUMMARY WELL SRD 9RD 15RD IS 31 32 NO WELLS k~_=':_m'J 4 5 6 7 SRD 9RD2 11 12 NO WELLS ~ 12-24 22-13RD2 31-13 31-14RD#2 33-14RD 24-13RD NO WELLS .ø6~ Information for AOGCC on Sbut-In WeDs Reg 20 ACC 25.115 DATE Mechanical Cond~tion SHUT-IN Dec-92 No known damage Oct-96 Communication between strings Mar-OO Tubing to Casing communication Oct-94 No known damage Dec-97 No known damage Jan-OO No known damage Jul-98 Hydraulic pump failure May-76 No known damage Feb-88 No known damage Dec-S4 No known damage Feb-S7 Bad Casing Feb-87 No known damage Jun-S7 No known damage Jun-S7 No known damage Nov-S2 No known damage Oct-OO Tubing to Casing Communication Jun-97 No known damage Jul-9S No known damage Oct-99 Tubing and Casing Leaks Mar-OO Tubing Plugged Page 2 Why weD was Shut-In Stopped taking water Mechanical integrity problem Failed MIT (Temperature anomaly) Gas well that watered out Produced water Depleted No production Stopped producing Failed WOo no production No injection on platfonn No injection on platf'onn No injection on platform No injection on platf'onn No injection on platfonn Won't take water Failed MIT (temperature anomaly) High Water Cut High Water Cut Mechanical integrity problem Scheduled for cleanout mA A!!!!Ó3 fJP . Future Utility of Well Potential WO candidate Potential WO or Coil tubing cleanout Injector Potential WO candidate Potential redrill candidate into Hemlock Convert to Rod Pump Completion. Potential redrill candidate. Potential gas producer. Potential redrill candidate Potential to convert to E & F producer Potential to convert to E & F producer Potential redrill candidate Potential redrill candidate '-" ---- Potential coil tubing clean out and return to injection. Injector Convert to water injector Possible conversion to water injector. Potential WO candidate Potential WO candidate DoWDload_SteveMcMaìnes.xLSShuUn_ Well_Status UNION OIL COMPANY OPERA TED PROPERTIES WELL DATA FIELD WELL &1kf....r.....Je1.-lJj)AL - DILLON 2RD 3 4 5 6 7 8RD 9RD2 11 12 13 14 15 16 17 18 SUMMARY NO WELLS ~j~ ~WhIt..~ 12-24 22-13RD2 31-13 31-14RD#2 33-14RD 24-13RD SUMMARY NO WELLS tljr1~U ~Iì Information for AOGCC on Shut-In Wells Reg 20 ACC 25.115 DA TE Mechanical Condition SHUT-IN Dec-02 No known damage Dec-02 No known damage Jul-98 Hydraulic pump failure May-76 No known damage Feb-88 No known damage Dec-84 No known damage Feb-87 Bad Casing Feb-87 No known damage Jun-87 No known damage Jun-87 No known damage Dec-02 No known damage Dec-02 No known damage Dec-02 No known damage Dec-02 No known damage Dec-02 No known damage Dec-02 No known damage Nov-82 No known damage Oct -00 Tubing to Casing Communication Jun-97 No known damage Jul-98 No known damage Oct -99 Tubing and Casing Leaks Mar-OO Tubing Plugged Why well was Shut-In Platfonn shut-in -- uneconomic Platfonn shut-in -- uneconomic No production Stopped producing Failed WO, no production No injection on platfonn No injection on platfonn No injection on platfonn No injection on platfonn No injection on platfonn Platfonn shut-in -- uneconomic Platfonn shut-in -- uneconomic Platfonn shut-in -- uneconomic Platfonn shut-in -- uneconomic Platfonn shut-in -- uneconomic Platfonn shut-in -- uneconomic Won't take water Failed MIT (temperature anomaly) High Water Cut High Water Cut Mechanical integrity problem Scheduled for cleanout Page 3 ttJ to/' II//Of A~lc~T;í 611 . Future Utility of Well None None None None None None None None None None None None None None None None -' ~ Potential coil tubing clean out and return to injection. Injector Convert to water injector Possible conversion to water injector. Potential WO candidate Potential WO candidate WeICCouncShuCIn_Status_2004_Complete.XLSShuCIn_ Well_Status UNION OIL COMPANY OPERA TED PROPERTIES WELL DATA FIELD WELL ~~AL-DILLON 2RD 3 4 5 6 7 8RD 9RD2 11 12 13 14 15 16 17 18 SUMMARY NO WELLS 1XIl[=~~ ~,I~~,,"·...~,r 11- 24 12-24 22-13RD2 31-13 31-14RD#2 33-14RD 24-13RD MUCI-2 GP52 GP55 SUMMARY NO WELLS 1 ~ 1UtîJ1 ,1;1 Information for AOGCC on Shut-In Wells Reg 20 ACC 25.115 DATE Mechanical Condition SHUT-IN Dec-02 No known damage Dec-02 No known damage Jul-98 Hydraulic pump failure May-76 No known damage Feb-88 No known damage Dec-84 No known damage Feb-87 Bad Casing Feb-87 No known damage Jun-87 No known damage Jun-87 No known damage Dec-02 No known damage Dec-02 No known damage Dec-02 No known damage Dec-02 No known damage Dec-02 No known damage Dec-02 No known damage Sep-97 Corroded tubing mostly pulled Nov-82 No known damage Oct-OO Tubing to Casing Communication Jun-97 No known damage Jul-98 No known damage Oct-99 Tubing and Casing Leaks Mar-OO Tubing Plugged Dec-03 Tubing to Casing Communication Aug-97 No known damage Aug-97 No known damage Why well was Shut-In Platform shut-in -- uneconomic Platform shut-in -- uneconomic No production Stopped producing Failed WO, no production No injection on platform No injection on platform No injection on platform No injection on platform No injection on platform Platform shut-in -- uneconomic Platform shut-in -- uneconomic Platform shut-in -- uneconomic Platform shut-in -- uneconomic Platform shut-in -- uneconomic Platform shut-in -- uneconomic Unsuccessful workover, perfs cemented Won't take water Failed MIT (temperature anomaly) High Water Cut High Water Cut Mechanical integrity problem Scheduled for cleanout Questionable value with limited H2O Drilling susp due to wet GP-53 well Drilling susp due to wet GP-53 well Page 4 115 G!JJrí/ I>/j /Ô S' I / -' 0 1f-pp - Future Utility of Well None None None None None None None None None None None None None None None None -' Possible redrill to the C-5 sand Potential coil tubing clean out and return to injection. Injector Convert to water injector Possible conversion to water injector. Potential WO candidate Potential WO candidate Possibly restore injection at a later date. Shallow depth allows flexibility for future redrills Shallow depth allows flexibility for future redrills - if v WelCCouncShuCIn_Status_Jan05 Rev.XLSShuUn_ WelCStatus R A; GRANITESINT PLATFORM ALASKA DRILLING WELL # 22 -13 RD #2 WATER INJECTOR UNOCAL 76 FINAL COMPLETION: 9/8/97 KB = 42.3' or 115' RKB from MSL CASING AND TUBING DETAIL L SIZE WT GRADE CONN TOP BOTTOM 26" Inside Conductor 47 294 18" 47 600 13 -3/8" 61 J -55 47 3,989 9 -5/8" 40 -43.5 N -80 47 9417 Window Cut in 9 -5/8" 6,643 6,670 L 7" 29 L -80 BTC 6,360 11,377 4 -1/2" 12.6 L -80 (Slotted) SC -BTC 11,215 13,922 Tubing 3 -1/2" 9.2 L -80 SC -BTC 43.15 10,354 z 7 ��� A 2 -7/8" 6.5 L -80 BTC 10,354 10,420 B C JEWELRY DETAIL E NO. DEPTH ITEM la G 1 10,325' Baker Locator , and 80 -32 Seal Assy (16.65') 2 10,332' 7" Baker SC -2P Retrievable Packer 3 10,325 80 -32 Seal -bore Extension (15.75') 4 10,386 X- Nipple (ID = 2.313 ") 5 10,420 Wireline Re -entry Guide Straddle Packer Assembly Ek Ems/ 1,2 A 4,935 9 -5/8 "x 7" Baker SC -1R Retrievable Packer 3 B 4,940 Mill -out extension (5.85') 4 C 4,946 -6,260 7" 29# L -80 Buttress Casing cc S5 5 D 6,261 -6,489 5" 15 # L -80 Buttress Casing E 6,499 K- Anchor A I G 6,499 Baker FA -1 7 "x 5" Permanent Packer with 85 -40 blank bottom I II GR/CCL ran in 12/97 shows tbg tail NOT present I,I C -5 SAND I II I I I I PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 10,534 10,602 C -2 6 10/11/96 2 -1/8" EJ z, I I 11,490 11,530 C -5 4 5/28/96 2 -1/8" H.C. TD = 13,821' 11,550 11,570 C -5 4 5/28/96 2 -1/8" H.C. MAX HOLE ANGLE = 83° 11,610 11,650 C -5 4 5/28/96 2 -1/8" H.C. GP 22 -13RD2 Final 9- 8- 97.doc DRAWN BY: MWD 9/18/97 Revised 2/29/99 ) ) ~ d-\~ \L\) r - \ '~"-Ð~lS Granite Point Platform . ,,1......- "" Well 22..13 Pressures Date May~~5 Oïtt . tbg .~~~~ 1j':"6/811·þ8QP~. !~ 3/8·~~C8Q,Pr~~:8b~8.lnj~~.Commenia.... "f 0 0 23.0 .0 2 "" '''~ O·~ .... a I~.. ~.35· 0·' . n, '3 0 '--0 235 a 4 0 0 235 . 0 5 0 a ~35 0 ",. e o··Õ 235· 0 , ,.. 7 Q. Õ' 2å'5 0 8 0 .0 235 0 9 0 .0 235 '() "".1.0 .0 .0 ,~35 0 , '11 .0 "r a ~35 0 "12 .0 a 235 .0 13 Ò .0 235- .0 14 a .0 235 0 ' '''~<15 _.0" a 0 235" .0 16 '''0 O"'~ 235" .0 17 .0 " 0 235":::'·0 18 0 ,. 0 240 .0 19 .a .0 , ,235 .0 20 ·'0 0 235 .0 21 .0 .0 235\J1" ",a 22 .0 .0 24.0 .0 . '"'2ª .0 .0 ""24.0 0 24" '0 Ó 240 a 25.0 0 235 .0 26 .0 .0 235,".0 27' .0 .0 235 Ö )., 28 0 .0 "235 "ö . -29 ,9 Õ 235 0 3.0 Ö .0 2,~5 .0 31 0 .0 24Q a ~_"-- w,. . _III .,.,. A Total .0 Ö '.. 73.05 " .0 . Avg '0 , . .0.. 2,ª5.645161~ a Copies to Tom·Maunde"r/Jim ~egg: Fax 276-7542 . I '''" ......,.~,:-" _.,/W¡#·"-\-- : -' -, .0 #DIV/O :..._ :"1 ,,,.,,,., . SCANNEC JON 2· 1. 2005 £0"d £~99 9¿¿ ¿06 dd~ 0SNI~~~ "~~~W Wd 6Þ:~0 ~0-t0-Nnî STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: X Stimulate: Change approved program: Pull tubing: Variance: Perforate: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: 115' RKB above MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphio: P.O. Box 196247 Anchorage, AK 99519 Service: X Granite Point Field 4. Location of well at surface Log #3, Slot #2 8. Well number 2379' FNL. 1375' FWL, Sec. 13, T10N, R12W, SM 22-13RD2 ADL 18761 At top of productive interval C-2 9. Permit number 2020' FNL. 892' FEL, Sec. 13, T10N, R12W, SM 1960750 At effective depth 11,135' 10. APl number 2015' FNL. 437' FEL, Sec. 13, T10N, R12W, SM 50- 733-20095-02 At total depth 11,984' 11. Field/Pool 1995' FNL, 2141' FWL, Sec. 18, T10N, R11W, SM Granite Point Field/Tyonek 12. Present well condition summary Total depth: measured 13,934' feet Plugs (measured) true vertical 10,811' feet Effective depth: measured 11,135' feet Junk (measured) true vertical 9,740' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 247 26' Driven 294 294 Surface 553 18" 1050 sx 600 600 Intermediate 3942 13-3/8" 668 sx 3989 3975 Production 6596 9-5/8' 8645 sx 6643 6616 Liner 5017 7" 9755 sx 11377 9906 2707 4-1/2" Slotted Uner 11215- 13922 10799_ Perforation depth: measured RECEIVED Slotted liner ,rue verticalDEC 30 2002 Tubing (size, grade, and measured depth) 3-1/2', 9.2#, N-80 323' MD 2-7/8, 6.4# N-SO 10,407' MD ~]~,S~(E[ 0il & Gaa Cons. Commission Packers and SSSV (type and measured depth) Baker SC-1R pkr @ 4987', Baker SAB pkr @ 6459', Baker SC-2P pkr @ Camco SCSSV @ 323'. 13. Attachements Description summary of proposal: Detailed operations program: BOP sketch: 14. Estimated date for commencing operation 15. Status of well classificaUon as: N/A 16. If proposal well verbally approved: Oil: Gas: Suspended: Name of approver Date approved Service: X 17. I hereby certify ~at t~foregoing ~e~o the best of my knowledge..jeff Signed: Title: Waterfolld technician Date: 12/27/2002 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval No. Plug integri~._~_ BOP Test._.~ Location clearance. (~ . r'~ Mechanical Integrity mest~_ Subsequent form required 10-~'~ '["~1~"~'~,~,, Approved by order of the Commiesioner ~-'~----~ ~ f~ Commiesioner Date ~//2//~ "~ Form 10-403 Rev 06/15/88 . BD S BFL UNOCAL KB = 42.3' or 115' RKB from MSL A B C E G 1,2 3 4 5 = 13,821' MAX HOLE ANGLE = 83° GRANITE~INT PLATFORM WELL # 22-13 RD#2 WATER INJECTOR FINAL COMPLETION: 9/8/97 SIZE WT CASING AND TUBING DETAIL GRADE CONN TOP BOTTOM 26" Inside Conductor 18" 13-3/8" 61 J-55 9-5/8" 40-43.5 N-80 Window Cut in 9-5/8" 7" 29 L-80 4-1/2" 12.6 Tubing 3-1/2" 9.2 2-7/8'}~, 6.5 BTC L-80 (Slotted) SC-BTC 47 294 47 600 47 3,989 47 9417 6,643 6,670 6,360 11,377 11,215 !3,922 L-80 SC-BTC 43.15 10,354 L-80 BTC 10,354 10,420 JEWELRY DETAIL NO. DEPTH ITEM 1 10,325' 2 10,332' 3 10,325 4 10,386 5 q0,420 Baker Locator, and 80-32 Seal Assy (16.65') 7" Baker SC-2P Retrievable Packer 80-32 Seal-bore Extension (15.75') X-Nipple (ID = 2.313") Wireline Re-entry Guide Straddle Packer Assembly A 4,935 B 4,940 C 4,946-6,260 D 6,261-6,489 E 6,499 G 6,499 9-5/8"x 7" Baker SC-1R Retrievable Packer Mill-out extension (5.85') 7" 29# L-80 Buttress Casing 5" 15 # L-80 Buttress Casing 'K- Anchor Baker FA-1 7"x 5" Permanent Packer with 85-40 blank bottom GR/CCL ran in 12/97 shows tbg tail NOT present PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 10,534 10,602 C-2 6 10/11/96 2-1/8"EJ 11,490 11,530 C-5 4 5/28/96 2-1/8" H.C. 11,550 11,570 C-5 4 5/28/96 2-1/8" H.C. 11,610 11,650 C-5 4 5/28/96 2-1/8" H.C. GP 22-13RD2 Final 9-8-97.doc DRAWN BY: MWD 9/18/97 Revised 2/29/99 40 0' 200' 400' 600' 60 GPP 22-13RD#2 10117100 Temp Survey After 5 days of Injection and 12 hrs SI 80 100 120 140 160 180 800' 1,000' 1,200' 1,400' 1,600' 1,800' 2,000' 2,200' 2,400' 2,600' 2,800' 3,000' 3,200' 3,400' 3,600' 3,800' 4,000' 4,200' 4,400' 4,600' 4,800' 5,000' 5,200' 5,400' 5,600' 5,800' 6,000' 6,200' 6,400' 6,600' 6,800' 7,0OO' 7,200' 7,400' 7,600' 7,800' 8,000' 8,200' 8,400' 8,600' 8,800' 9,000' 9,200' 9,400' 9,600' 9,800' 10,000' 10,200' 10,400' 10,600' 10,800' 11,000' 11,200' GP 22-13RD2 Temp Survey 10-17-00.xls GRANITE POINT PLATFORM APl # 50-733-20095-02 GRANITE PT. ST. GP # 22-13RD2 WELL HISTORY LAST WORK: 9/9/97 Date Finaled Work Performed 1996 4-18-96 Spud 4-28-96 Reached TD 5-7-96 Completed as 2-7/8" gas lift completion with slotted liner across C5. 5-11-96 5-12-96 Attempted to bring on well. Chloride water analysis. Well producing high water cut. 5-16-96 Gas Lift and Static Pressure Survey from 10550' WLM. 5-28-96 70O# Perfed w/2-1/8" Hollow Carrier, 0 deg phased, 4 SPF: C5 11,490 - 11,530' MD C5 11,550 - 11,570' MD C5 11,61 0 - 11,650' MD Tight while POOH from 7450' - 8300' & 8700' - 10300'. Pulled over at 8320' and 650# over at 10270' while POOH. IP = 168 BPD, 70% wcut. 6-3-96 Water & scaling tendency analysis. 7/11-18/96 SBHP Survey. 10/9-10/96 PERF - The slickline dummy gun run is currently underway. C2 perfs are planned for this evening The dummy gun run was successfully run to 10,700' SLM on 10/10. The dummy gun was worked through 8,646' SLM & 8,966' SLM while running in the hole. Ran CCL-GR-TDT log from 10,700' WLM to 9,850' WLM. Perfed C2 F/10,534 - 10.602 w/2-1/8" enerjet guns 6SPF on 10/11. Well on production @ 11:30 pm 10/11. Current rate is 148 BFPD @ 81% wcut, well appears unchanged by C2 perfs. 10/11/96 PF- Perforate C Zone W/2 1/8" Enerjet (Retr) Guns, 6HPF, 0 Phase C-2 10534' - 602' 68' Tbg tail @ 10,407' tbg. measurement = 10,421' TDT measurement. 10/21/96 Well Test - Test indicate no change in production since adding C2 perfs. 1997 8/31-9/2 9/3 9/4 9/5-7 9/9 1998 1999 2000 7/11 GRANITE POINT 22-13RD2 WORKOVER TO CONVERT TO A WATER INJECTOR: 9-5/8" CSG @ 9,471, 7" LNR @ 6,360' TO 11,377', 4-1/2" SLOTTD LNR @ 11,215' TO 13,922', · DAY 1-3 KILL WELL WITH FILTERED INLET WATER. WELL ON VACCUUM. ND TREE NU BOPE. PULL TBG HGR LOOSE. ClRC WELL. (TAKING 12 BBL/HR). POOH WITH 2-7/8" TUBING. CHANGE RAMS AND TEST--OK. PU 5" DRILLPIPE. RIH WITH 7" MECHANICAL CASING CUTTER. CUT 7" CASING @ 6,215'. RIH WITH PACKER RETRIEVEING TOOL. DAY 4 RIH WITH PACKER RETRIEVEING TOOL. ENGAGE SC-1 PACKER AND ATTEMPT TO RELEASE. POOH. RIH WITH 7" MECHANICAL CUTTER AND CUT 7" CASING @ 5,025'. POOH. RIH WITH RETRIEVING TOOL AND ATTEMPT TO RELEASE PACKER. POOH. RIH WITH BURNING SHOE AND BURN OVER PACKER F/4,993' TO 4,995'. DAY 5 RIH WITH SPEAR. COULD NOT RETRIEVE SC-1 PACKER. POOH AND RIH WITH MILL AND PRT. MILL PAKER UNTIL IS STARTED MOVING DOWN HOLE. COULD NOT PULL FREE. RIH WITH SPEAR AND TAG FISH @ 5,025'. COULD NOT PULL PACKER FREE-FISH FALLING OFF SPEAR. DAY 6-8 (CHANGE OUT CATCH ON SPEAR RIH AND RETRIEVE 7" AND 5" CASING AND K-ANCHOR. RIH WITH MILL AND PRT. MILL SAB PKR @ 6,447'. POOH WITH PACKER AND 2-7/8" TUBING. RIH WITH SEAL ASSY AND STAB INTO PACKER. RU SLICKLINE AND DRIFT TUBING TAIL. RD SLICKLINE AND POOH WITH SEAL ASSY. RIH WITH BOT'S FA-1 PERMANENT PACKER AND SET @ 6,500'. TEST ANNULUS TO 1,000 PSI. RIH WITH 5" AND 7" SCAB LINER. REVERSE ClRC IN CORROSION INHIBITOR. STAB INTO PACKER @ 6,447'. TEST ANNULUS TO 1,500 PSI. SET SC-IR PACKER. POOH WITH SETTING TOOL. DAY 9 TEST 9-5/8" CSG, STRADDLE PACKER, 7" CSG T/3000' PSI FOR 30 MINS, OK. ND BOP, NU TREE. TEST TREE TO 5000' PSI. PREP T/MOVE RIG. W L- 2.30" G R to 11,128' 7/12 1'0/11 WL - Bailed w/2.25" DD Bailer, tagged fill @ 11,127' WL- RIH w/2.25" , Sat down @10,330' worked by and tagged fill @ 11,142'. Ran Temperature survey to 11,135'. Note: Hung up in tubing tail on way out. UNOCAL ) ~'~Alaska GPP 22-13RD2 Permit # 1960750 API# 50-733-20095-02 Packet cover sheet GPP 22-3RD2.doc jjd NOTE TO FILE Granite Point 22-13RD2 PTD 196-075 302-400 Unocal has applied for a time extension to perform an MIT on this injection well, which has not recently injected. This note evaluates Unocal's request and recommends approval of it. The record indicates that the well was sidetracked and originally completed as an oil well May 1996. The well was converted to an injector and almost immediately showed tubing x IA communication. Unocal performed diagnostics and determined that the tailpipe, for unknown reason had dropped off. Unocal requested permission to keep the well in service by conducting more frequent MITs and providing daily rate and pressure monitoring information. Injection was stopped in late July 2000. Unocal has not returned the well to service. A requirement of the sundry (398-021) that returned the well to service was to perform bi-annual MITs. Since the well has not been in service, Unocal is requesting a time extension for the required survey.-The next MIT is due in March 2004. While in service and since shut-in, Unocal has been providing the monthly monitoring reports. The well still has some surface pressure, although the maximum reported value as of the end of February was about 100 psi. Area Injection Order 11 allows injection into the Central Granite Point field. The BHL of well 22-13RD2 is located in the covered area. The portion of aquifers beneath Cook Inlet described by a 1/4 mile area beyond and lying directly below the southern portion of Granite Point Field are exempted for Class II injection activities by 40 CFR 147.102(b)(2)(A) and 20 AAC 25.440(c). Granting Unocal's request will not endanger any fresh water. I recommend that Unocal's request for a time extension be granted. At this time, Unocal has indicated that further diagnostics are planned on a sister well on Granite Point Platform. Unocal should continue to provide the monthly monitoring information and prior to the end of 3rd quarter 2003 provide the Commission with an action plan for this well. This requirement will be in addition to the regulatory requirement to provide an annual report on SI wells. Tom Maunder, PE Sr. Petroleum Engineer March 17, 2003 6O0 Granite Point 22-13RD2 500 400 300 200 100 25O 200 150 100 5O -,- tbg Granite Point Platform Well 22-13 Premturee Date JAN. 2002 ~ ~oo',~~o, ....~o .,. o ,, ....~ ......... J00 50 ,, 1t01 0 ........ -4:-" 100 ..... 50 110 '' 0 "5 100 60 , 110 0 '~ 100 50 110 0 I III i I I ~ '" 100 "50 ..... 110 ...0 ~--8 .. 100 , , 60 .... 95 ,, 0 ~:9 .. 100 ,,. 50 .. 95 .... 0 . -"3-0 lOO 6o 95 0 ..... :'i:~._'._-' ._.:.'- ~oo..:' '~o' :', ~5 ..... ,,, -o -'12 100 ,'50 95 ..... 0 -"~§ ............. 400 5o o5.... o, ---~?~'_:::;: ...... '~oo .... . ~o' .,. ~5 .., o _!~ .............. !oq ._ 40 .. o5 .... o ..!~ .................. !00 ....40 100 ........ 0 ~? ~oo 40 ,, loo. o 18 ..... ~00 ' 40 .,-... 100 0 ........................... .... ~ ........100 ""'40 t00 O' ........ '"-~-~..... lOO ..... '~o ..... '10o: o ....... , .... ~ ...... loo ,,.40 ,,,... so o ": ~:_'::'"::.' : 100 40 qq 0 23 ...... !oo ~6' ,.. oo ,. o ........... ~_~ .............. "16o..... 40 oo. o ........... 28 100 40 O0 0 Illl L .... ~ .... 27 .!00 , 40 , 90 ..... 0 28 t00 40 .... O0 .. 0 I'20 ~-'-- i'6~ 40 loo o ..... ~d ....... 100 "40 ..... 100 0 .... ........ lOO ' ............................................ 40 ~oo ................... o ..................... Tot. Il_ i" i ^vg [. _ ...... _ ..... :.~. , --.. Copies to Wendy Fax 276-7542 R E C E i-E~ i 2002 Alaska Oil & Gas Certs, SCANNED JUN ~'4:2002 7,;, · .4 'b'~'::J'~-J J_J_O~ T 14~iO--I.LU-Id "-LH T Od "'=a J_ T biU~J~D Md ~ T -' ~'EJ ~:0-- T ~--~r'=a .4 Granite Point Platform Well ;12.15 Pr#~um~ Da/e 8'ep-01 2'"' 20o' .... ~0 ' 200 3 ,., 200 gO 200 ............. _ 4 200 JO0 200 0 5 ,. 200.... ~oo ~o , o .... , .,,., , i , i , ,.i . ~,L_ ~ , e , _2.oo: -- ~oo, ~9o , o · - -7 200 100 190 0 ...... I I II_. . I a .i 200. ,.. 100 190 ., .0 ..... _ 9 .,,: 20o ,, 'ioo ~90 0,._ il · i i I I .l_ 10 200 gO 190 ...... do -- b ......... --' 11 190 90 " II ... · - i · i . i i !1 ..... iL ~!1 ill. I . I 12 190 90 190 O! __ · 1 I I _ I I - 13 ' i{i0 ' I~0 1~ ":0 I · I I ._ II I I .... 14 190 9O 190 0 I II llll-- J'_l ., -- ~1___. I I I J '1~ ,!.9o ~ 90 , , !90 ,.__0 , , . 16 190 90 190 0 ~!~ ' -' ' ...... O'' .......... .... t9~' :- 90 .,_ 190 .... ' i u II i .. . 16 -, .',~90, 90 190 0 --- ' I I1' I .... I I I I II I I 1~ 1~3 90 190 - -0 .. - IlL ..... I ii._ I I I 20 ' 190 gO 190 , ,., j! ....... i i . ~ -- :~"" .... 2;1' 190 , 90 ._ 1~0 _. 0 ............ .__ ~-2 190 90 190 0 . _ 23" 190 ........ gO ' 190 ' 0 ....... iiii iiiii I II - I i i ii II II I 24 I ilo "90 190 0 2~, ,- 'i90' . 90 . 1i'0 ' I I I _ I l 2~ ~0 ,, ;o , ,, ~7o. o .... 27 190 90 170 0 _ ... I II I i~11 II I 28 , !90 , 90 ..... 170 Oi . I I i 1, .2.9. , 1gO 90 170 0 I I I II .... 30 '-, ~9o ~i3 ' ~7o "oi .. . 31 l'ot~il ' " ' ' ' J .... ' ...... Il .... I ... I I .... III .... ....r, Avg .............. Gopieg to Wendy Mahan; Fax 276-7542 SCANNED JUN 2',~ 2002 Granite Point Platform Well ;1~.15 Preeeure~ Dire Au;-01 20o - . o ....... ............. , , , ! r .__:.L , :2 200 -~i3~ .... 210 O' .I i i ! i l il _. i i i ill ... i iq_--- _._ 3 200 100. 210 4 --2-~0 ..................... 100 ........ 21-0~ OI ..... i~ L ........ .in I I $ 200 100 -' 210 0 il _ill ,11 . . i i .a_.. , 2o,o , , , loo 2to ....... o; ....... 7 200 10~3 210 0 ................. , , ,, ,t,_ 8 200 100 210 01 i i . ,, , .,, :- _.J~ "' 9 200 100 210 0 ii 10 200 100 ' '" 210 0 11 200 ..... 100 ...... 210 0 ............ 12 200 - ' 100 :~i} "' ' ........... ~3 2o~ .......... ~oo '2~ o ....... , , ,, .... :.-- . ..... ILL_. 14 200 100 210 '0 ........ .u ~1-.£ .-..:: i Il 15 200 ......... _!__00_ 210 .... 0 ......... !6 .... 2.00, 100' 210 0 · i ___~ltI. FI. . I II I ' ' ' 17 200 100!" 2.10 0 ' " - 18 200 100 .......... 210, .. 0 ... ' -'-lg 200 100 210i 0 _..20 .......... .200 ............ ~ ........ i~O 210 0 .... 2_1 ................... 200 --- 100 210 ........ i ..... . ...... ii . -. 22 200 100 . 2.10 .... O; ....... 23 200 , .l,,O0, ,, 210 ., O' . .... - .... 24 200 100 210 ____: ~ .... 200 100 .... 210 0 ...... _2~ ..... 2.00. ' . ..... 100 210 .... 0 _.. " .Z7 ...200 100 ;10 0 · I I I ......... ' .... II ' Il ' 28 200 , 100 210 0 29 200! I~)0 - 210 i m · aa I I ii Il i :.::~-.0_::_ ::::::_- ...... :_-2i~OI ............... 80 200 0 ..... ~_! 2oo~ ..... oo '~i3o o . Totai- ' ...... ' " '" "' .... ' ......... .-- l Avg ......... I. i i i111 i i i i Copies tO Wendy MnMn; Fax 276-7542 SCANNED JUN 2'~ 200Z Granite Point Platform Well 22-13 D~te Jun-01 · .. ........ oat... _T~g?;~. g.~e",ceg pree.. ~:S 3m" ceg ~:' a~??.;.,~nle~ ~:ommen~ ,,,~i,' 1 150 1~:5 2201 0i , LL 2 150 125 220 O I 3 150 125 220 .0! .... "4 ..... ~.' 220 140 220 -' 0 i i i i,m ............ ~_ . i i · 5 22O 140 22O 0 .............. J~q, -, i i 6 ............... 220 140 ..............220 0 .... 7 .., 210 130 220 0 ' ' a Ill. 8' 210 130 220 0 9 210 130 220 0 . ~'~c '. .... I ,,, I_. l.J I 10 210 . ~ .1..3.._0. 220 , 0 .-. _._ m,.-.. __.:_:.1..1, '2i0 - 130 220 -- 0 --- _ ~..... J.. ..~,:.j, 12 210 130 220 0 15 210 150 ~.0 0 i J4N-'.. - .,_ll_h I t4 210 130 220 0 ~---:-_,. J .............. ,, ,, 15 210 130 220 0 . iii- i ..... 16 210 130 220 0 ~ ........ ~_:. ........... . ..., ....... - 17 210 130 220 0 ,_ _ ....... .. ~, i P.. 18 200 120 220 0 _.. ~, ~....;- ,.,.. lO 210 120 220 0 ii i ._. JLL · i iii 20 210 120 220 '0 21 210 ........ i~20 220 0 ........... 22 200-, : ..... 12d .............. 220 0 " 23 20,0, 120 ........... ~t~ .'~. ..... 0 ' , '" 24 200: 1~o 220 . o ii 25 ........... 2001 110 220 - ..... 0 ...... -. , ---. ,~ · 26 200 110 220 0 i ii ii1~ .... iii 27 ......2_Q_O.,_ . 110 220 0 28 2001 1t0 ' 220 0 .... I ......... i11 29 200 110 220 0 ....... 111 . . . . .., , ,., ... .... 30 2{30 L.. 110 220 0 ..... - ,- - _. _ ill. i 31 200i 110 220' 0 ..... ii ii · i----: ......... I I To~l .... ........ : ii i i ii --,,v~ ............. ::1 .... . , . ...... Copies to Wendy Mahan; Fax 276*7542 SCANNED JUN 2'4 2002 Granite Point Platform Well 22.13 Pre.utes Date March I I I II .... 1 300 160 190 0 2 300 190 190 ~;~.~_..~ ::.~, T __ 3 30O 190 190 o _~ ...... 300 '1go 190 0 5 300 190 190 0 I 6 300 200 160 0 -- --- 7 300 200 180 0 8 300 180 180 o ,-, 9 3OO 160 180 0 10 300 200 160 0 11 3o~ ................ ~ppJ loo o 12 300 175q........ - ....... 190 0 13 275 170 190 0 14 275 170 190 Oi 15 276 170 190 0 16 275 170 190 0 i 17 275 ~70 ,!0~ .... 0 18 275 170 190 0 19 276 170 190 0 ___20 .... 275 170 190 0 21 275 t70 190 0 22 275 170 190 0 23 276 170 190 0 24 276 170 190 0 - '~' ~- ' ............... 25 276 170 190 0 ., 26 250 160 190 0 27 _ 250 "' ~160 190 ~ 0 28 250 15o ~oo o .__29 260 150 .......... 19~ ' 30 250 t50 19~'-'''-''~=-:- ..... --~i'--~=' ......... ' ..... '----"' 31 250 150 190 0 Ave i-, Copies to Wendy Mahan; Fax 278.7542 RECEIVED APR 0 Z 2001 ~ Oil & Gas Cons. Comm A~c~orage SCANNED JUN 2'4 2002 · iiiF `ii, _ __ -- ii - - 7 SCANNED JUN 2,',~ 2002 Granite Point Platform Well 22-13 PreB~ures Date Nov-00 Date TbQ Pre,e. g sm" c~ Pm'ss, 13 318" ~ Press, I~i~l~. In~,ected c-~mlments 1 700 625 1 ~ 1 .... ~ ............... ~00 ........ 600 13S 0 3 700, 600 135 O~ 4 7OO 57~ 140 0 ........... 5 700 '-575 ...... 1~§ 0 6 700 550 140 0 _. ! 7 650 550 140 0 ..... _ . · ..__ ,_.-~_..~- ......... 8 65O 55O 140 0 L~. I 9 65O 525 135 0 10 625 525 140 11 600 500 140 0 ,, 12 6001 ........ 500 140 0 . 13 600 500 140 . . 14 600 500 140 0 , , 15 600 500 145 0 ............. , . ........ 16 6.._00.i ........ 500 140 0 ....... 17 600 490 145 0 18 60O 450 145 0 19 600 450 145 20 60O 450 145 0 21 500 450 150 22 500 450 150 · ,, ,, , m, , , 23 500 45O 150 0 . ..2...4..,.il. _ , 500 42{3 150 0 25 ,500 420 150 0 .., m, ., .,_._ 26 500 410 150; 0 _,_, Jl_ ! i .2..7..I 500 400 150' 0 28 SO~ 400 150 0 2S 500 400 150 0 30 500 400: 155 0 ~- __ ,~*--_ 31 iii i ii.L_iii1 · .... I " I ! ... Copies lo Wendy Mahan; Fax 276-7542 SCANNED JUN 2'4 2002 UNOCAL~ TFIANSNtTTA.L To: ~ FR OM: ' ¢'~ ./ - ,/- No. OF DA TE; T~E; ~__~,~. CONTAC, T: E ×'T'; ___ J ~ SCANNED JUI~ ~ & tOO~ Granite Point Platform Well 22.13 Pressum~ IC~ (,, -(:::3 ~'1 ~- Date Aug-00 Date Tbg Press. g .~l""CS~l Pm... '!3 ~,/,.a'~,ceg Pres~. 'i~l~. inle~ed Comments ' 1 1450 1300 230 0 Well 22-13 shut in for chds Ruff ... 2 1400 1240 220 0 3 13~5 1200 ....... 220 0 · 4 13OO 1160 22O 0 5 1250 1120, 220 0 6 1200 1100 ....... 220 0 Well 22-13 shut in for chri~uff 7 12oo 11oo "~'21s o e 120d " 1100 22~ ...... 0 9 1150 1050 220 O 10 1100 1000 215 0 .. ,... ~ _.J. · 11 1100 1000 215 0 · _'Jill II _, -,. 12 1050 950 215 0 13 1050 900 215 .~ .. ........ , 14 1000 900 215 0: , . , 15 1o0o , aso 215 ...o.i 16 1000 850 215 0 ._ 17 950 825 210 0 18 925 800 215 0 ·., .~1 _ _.~ i 19 g00 800 215 0 --'. i ...... · i~ l 20 900 775 215 O 21 900 775 215 0 mi --- i L _p-~ 22 900 750 215 0 i i q,j__ 11_. 23 900 750 215 0 :z4 6oo -'7oo 21o: 25 8O0 700 210 0 ~ ... · ,_, _ _ 26 800 700 210 0 __1 - .._,_u, ,, 27' 800 700 210 0 ,, -- ,~ i .111, ,,, , 28 800 680 210 0 29 800 650 210 0 . 30 775 650 210 i i ii . ij~ll 31 750 650 210 0 Copies to Wendy Mehan; Fax 276-7542 SCANNED JU~ Granite Point Platform Well 22-13 Pressures December 1999 -D~.te_iI-T~in_q__ .P..m.s's./19 518" Cs[3 Press:Ill3 3/8" Csg'Pmss.II Bbl,. Injected Il- comments ___ ~ .... .- ... ........... 11 ..... ~ ~s-~o '?~ , ~ ................. ....... ~ .._ 15 ~o __.~oo ~o. ~ ~ 16 ~7oo ~ ~ /7~ 20 , ......... I 21 _ 25 Zffo~ ~7~ ....... ~o 27 .... ~.~ z~ ~-o . 1~5~ 31 ---%l 5'0 2~ X~' ,,170 ~o m~.~ ,, eb Il P ~F Copies to Wendy Mahan; Fax 276-7542 =~123w~forms[WELL2213.WK4 RECEIVED ,JA;~,/ 03 2000 OjJ & Gas C0rls. ~r, horage_ . SCANNED ,JUN Z;~ 2002 ,_DATE t 2/15/97 12/16/97 TIME 22:30 22:38 22:45 23:00 23:15 23:30 23:45 24:00 00:15 00:30 00:45 01:00 01:15 01:30 01:45 02:00 02:15 02:30 02:45 03:00 03:15 03:30 03:45 04:00 04:30 05:00 05:30 06:00 CHOKE TUBING CASING PRESSURE ... 9 5/8 13 3/8 6 6 8 8 8 8 8 8 8 10 16 16 18 18 18 18 18 18 18 18 18 20 2O 2O 20 2O 0 1200 135O 1650 1800 1900 1975 20OO 2100 2100 "'*2520 2650 2800 2875 290O 2990 3OOO 3010 3040 3055 3075 3100 3270 3400 350O 35OO 2000 2050 2000 1950 1900 1860 183O 1790 1760 1740 171¢ 1675 1600 1600 1600 1590 1590 2000 2000 2000 1990 1975 1980 1990 199O 1990 / 110 110 110 110 110 110 110 110 110 100 100 9O 90 9O 9O 9O 9O 100 100 95 95 95 95 95 95 95 RATE 1200 960 96O 90O 840 872 824 812 754 737 979 985 993 943 937 928 940 920 920 909 916 1109 1010 995 946 912 ,'~, i,,,,,.~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended .well: Alter casing: Repair well: Plugging: Time extension: Stimulate:' Change approved program: Pull tubing: Variance: Perforate: Other: Temp. Shut-in 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: x 115' RKB above MSL 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 Leg #3, Slot #2 8. Well number 2379' FNL. 1375' FWL, Sec. 13, T10N, R12W, SM 22-13RD2 ADL 18761 At top of productive interval 9. Permit number 1995' FNL, 1616' FWL, Sec. 18, T10N, R11W, SM 96-75 At effective depth 10. APl number 50- 733-20095-02 At total depth 11. Field/Pool 1995' FNL, 2141' FWL, Sec. 18, T10N, R11W, SM Granite Point Field/Tyon.&kf--~ 12' Present well c°nditi°n summary Total depth: measured 13934 feet Plugs (measured) true vertical 10811 feet Effective depth: measured N/A feet Junk (measured) true vertical N/A feet Casing Length Size Cemented Measured d e ~i,A%~ ~O~ vertical depth Structural Conductor 247 26" Driven 294 294 Surface 553 18" 1050 sx 600 600 Intermediate 3942 13-3/8" 668 sx 3989 3975 Production 6596 9-5/8" 8645 sx 6643 6616 Liner 5017 7" 9755 sx 11377 9906 2707 4-1/2" Slotted Liner 11215 - 13922 10799 Perforation depth: measured Slotted liner true vertical ORIGINAL Tubing (size, grade, and measured depth) 3-1/2", 9.2#, N-80 323' MD 2-7/8, 6.4# N-80 10,407' MD Packers and SSSV (type and measured depth) Baker SC-IR pkr @ 4987', Baker SAB pkr @ 6459', Baker SC-2P pkr @ 10364" MD Camco SCSSV @ 323'. 13. Attachments Description summary of proposal: x Detailed operations program: BOP sketch: 14. Estimated date for commencing operation 15. Status of well classification as: 1/16/1998 16. If proposal well verbally approved: Oil: Gas: Suspended: Name of approver Date approved Service: X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: ~)~ (., ¢~t 60~..~ Title'0 ' ' Date: 1/1 998 FOR COMMISSION'US~~E' NLY 6/1 Conditions of approval: Notify Commission so representative may witness IApproval No.~,,~ ~,~ Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- /~0/.~ ~-~..r- ~4;~'O~((2¢4,t~ Original Signeo By David W~ Johnston(/'~ ~ //,(~ ~,,? Approved by order of the Commissioner .... Commissioner Date Approved Cupy R~turnaci. - Form 10-403 Rev 06/15,88 i ~ o~..'.~'p} ~__.' / SUBMIT IN TRIPLICATE Attachment to 10-403 for 22-13RD#2 dated 1/16/98 Description summary of proposal: This well was converted to a waterflood injector last September. At which time it passed its MIT. Injection began on December 13, 1997. After about 8 hours of injection we recognized that the 9 5/8" casing pressure was increasing and we shut in the well. Over the next two days we tested the well in various configurations and determined the well would pass the conventional MIT, but when injection resumed the casing would pressure up again (i.e.. A one-way leak into the casing. A CCL log was run on this well on December 24 and the results are somewhat disturbing when compared to the CCL log run during the perforating of the well after the workover. The CCL run when perforating clearly shows that the tail pipe · tubing joint - X nipple - tubing joint was intact. The most recent CCL shows that no tail pipe is present which most likely indicates that a large portion of the assembly below the packer ( including the seal bore assembly) is no longer attached to the packer. The well is currently shutin. We are in the process of determining a plan of action and will file another 10-403 as soon as the plan is determined. Due to a recent crane incident we are unable to repair the well at this time. An investigation is currently being conducted and a plan to repair the crane is being developed. S i n~e.~,- Iw;~/~/'~ Christ~A/. Ruff Reservoir Engineer C.I. Reservoir Mgmt and Waterflood - .... STATE OF ALASKA ALASKA O,-AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: Pull tubing: x Alter casing: Repair well: Other: Convert to water injector 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (Unocal) Development: x 115' RKB feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 Service: Granite Pt Field 4. Location of well at surface 8. Well number 2379' FNL, 1375' FWL, Sec. 13, T10N, R12W, SM GP 22-13RD2 At top of productive interval 9. Permit number/approval number 1995' FNL, 1616' FWL, Sec. 18, T10N, R11W, SM 96-75/397-51 At effective depth 10. APl number 50-7733-20095-0 At total depth 11. Field/Pool 1195' FNL, 2141' FWL, Sec. 18, T10N, R1 lW, SM Granite Pt Field/Tyonek 12. Present well condition summary Total depth: measured 13934' feet Plugs (measured) true vertical 10811' feet Effective depth: measured N/A feet Junk (measured) true vertical N/A feet Casing Length Size Cemented Measured depth True vertical depth Structural 247 26" Driven 294 294 Conductor 553 18" 1050 sx 600 600 Surface 3942 13-3/8" 668 sx 3989 3975 Intermediate 6596 9-5/8" 8645 sx 6643 6616' Production 5017 7" 9755 sx 11377 9906' Liner 2707 4-1/2" Slotted Liner 11215'-13922' 10,799' Perforation depth: measured 10,534'-10,602'; 11,490'-11,530'; 11,550'-11,570'; 11,610'-11,650' true vertical 9,348'-9,405'; 9,974'-9,995'; 10,006'-10,015'; 10,034'-10,058' Tubing (size, grade, and measured depth) 3-1/2" 9.2 lb/fi, L-80, 10,354' 2-7/8" 6.5 lb/fi L-80 10,354'-10,420' Packers and SSSV (type and measured depth) B.O.T. SC-1R pkr @ 4935', B.O.T. FA-1 pkr @ 6499' B.O.T. SC-2P pkr @ 10,332' 13. Stimulation or cement squeeze summary Intervals treated (measured,ORIGINAL Treatment description including volumes used and final pressure $ E P 2 4 1997 14. Representative Daily Avera.qe Production or Injection Data AI~-s~a .0il .& Gas Cons. O0rnmis~' OiI-BBL Gas-Mcf Water-Bbl Casing Pressure ~ril~o-rr~lg Pressure Prior to well operation 25 67 73 690 85 Subsequent to operation Haven't started water injection yet 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: Gas: Suspended: Service: Water Injection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: Dale A. Haines ~,",-~. c. ~ q-., Title: Drilling Manager Date: September 18, 1997 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE KB = 42.3' or 115' ICKB from MSL __A B C E G 1,2 3 4 5 GRANITE~OINT PLATFORM WELL # 22~13 RDg2 WATER INJECTOR FINAL COMPLETION: 9/8/97 CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 26" Inside Conductor 47 294 18" 47 6O0 13-3/8" 61 J-55 47 3~989 9-5/8" 40-43.5 N-80 47 9417 Window Cut in 9-5/8' 6,643 6,670 7" 29 I,-80 BTC 6,360 11,377 4-1/2" 12.6 L-80 (Slotted) SC-BTC 11,215 13,922 3~1/2~' 9~2 L~g~ SC.~BTC 43A5 JEWELRY DETAIL NO. DEPTH ITEM 1 t0,325' 2 t0,332' 3 10,325 4 10,386 5 10,420 Baker Locat[¢r, and 80-32 Seal Assy (16.65') 7" Baker SC-2P Retrievable Packer 80-32 Seal-bore Extension (15.75') X-Nipple (ID = 2.313") Wireline Re-entry Guide Straddle Packer Assembly A 6,49!) B 4,940 C 4,946-6,260 D 6,261-6,489 E 6,499 G 6,499 9-5/8"x 7" Baker SC-iR Retrievable Packer Mill-out extension (5.85') 7" 29# L-80 Buttress Casing 5" 15 # L-80 Buttress Casing K- Anchor Baker FA-I 7"x 5" Permanent Packer with 85~40 blm~k bottom I ~ TD = 13,821' MAX HOLE ANGLE = 83° PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 10,534 t0,602 C-2 6 t0/11/96 l L490 11,530 C-5 4 5/28/96 11,550 11,570 C-5 4 5/28/96 11,610 11,650 C-5 4 5/28/96 2-1/8" EJ 2-1/8" H.C. 2-l/8" H.C. 2-1/8" H.C. GRANITE POINT 22-13RD2 WORKOVER DAY 1-3 (8/31-9/2/97) 9-5/8" CSG @ 9,471 7" LNR @ 6,360' TO 11,377' 4-1/2" SLOTTD LNR @ 11,215' TO 13,922' KILL WELL WITH FILTERED INLET WATER. WELL ON VACCUUM. ND TREE NU BOPE. PULL TBG HGR LOOSE. ClRC WELL. (TAKING 12 BBL/HR). POOH WITH 2-7/8" TUBING. CHANGE RAMS AND TEST--OK. PU 5" DRILLPIPE. RIH WITH 7" MECHANICAL CASING CUTTER. CUT 7" CASING @ 6,215'. RIH WITH PACKER RETRIEVEING TOOL. DAY 4 (9/3/97) 9-5/8" CSG @ 9,471 7" LNR @ 6,360' TO 11,377' 4-1/2" SLOTTD LNR @ 11,215' TO 13,922' MUD WT: 8.4 PPG RIH WITH PACKER RETRIEVEING TOOL. ENGAGE SC-1 PACKER AND ATTEMPT TO RELEASE. POOH. RIH WITH 7" MECHANICAL CUTTER AND CUT 7" CASING @ 5,025'. POOH. RIH WITH RETRIEVING TOOL AND ATTEMPT TO RELEASE PACKER. POOH. RIH WITH BURNING SHOE AND BURN OVER PACKER F/4,993' TO 4,995'. DAY 5 (9/4/97) 9-5/8" CSG @ 9,471 7" LNR @ 6,360' TO 11,377' 4-1/2" SLOTTD LNR @ 11,215' TO 13,922' MUD WT: 8.4 PPG RIH WITH SPEAR. COULD NOT RETRIEVE SC-1 PACKER. POOH AND RIH WITH MILL AND PRT. MILL PAKER UNTIL IS STARTED MOVING DOWN HOLE. COULD NOT PULL FREE. RIH WITH SPEAR AND TAG FISH @ 5,025'. COULD NOT PULL PACKER FREE-FISH FALLING OFF SPEAR. DAY 6-8 (9/5-9/7/97) 9-5/8" CSG @ 9,471 7" LNR @ 6,360' TO 11,377' 4-1/2" SLOTTD LNR @ 11,215' TO 13,922' MUD WT: 8.4 PPG CHANGE OUT CATCH ON SPEAR RIH AND RETRIEVE 7" AND 5" CASING AND K-ANCHOR. RIH WITH MILL AND PRT. MILL SAB PKR @ 6,447'. POOH WITH PACKER AND 2-7/8" TUBING. RIH WITH SEAL ASSY AND STAB INTO PACKER. RU SLICKLINE AND DRIFT TUBING TAIL. RD SLICKLINE AND POOH WITH SEAL ASSY. RIH WITH BOT'S FA-1 PERMANENT PACKER AND SET @ 6,500'. TEST ANNULUS TO 1,000 PSI. RIH WITH 5" AND 7" SCAB LINER. REVERSE ClRC IN CORROSION INHIBITOR. STAB INTO PACKER @ 6,447'. TEST ANNULUS TO 1,500 PSI. SET SC-IR PACKER. POOH WITH SETTING TOOL. DAY 9 (9/9/97) 9-5/8" CSG @ 9,471 7" LNR @ 6,360' TO 11,377' 4-1/2" SLOTTD LNR @ 11,215' TO 13,922' MUD WT: 8.4 PPG TEST 9-5/8" CSG, STRADDLE PACKER, 7" CSG T/3000' PSI FOR 30 MINS, OK. ND BOP, NU TREE. TEST TREE TO 5000' PSI. PREP T/MOVE RIG. '- STATE OF ALASKA - ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: x Variance: Perforate: Other: Convert to WINJ. 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: x 115' RKB above MSL 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 Leg #3, Slot ~-2 8. Well number 2379' FNL 1375' FWL, Sec. 13, T10N, R12W, SM 22-13RD2 ADL 18761 At top of productive interval 9. Permit number 1995' FNL, 1616' FWL, Sec. 18, T10N, R11W, SM 96-7,___~_5 At effective depth 10. APl number 50- 733-20095-02 At total depth 11. Field/Pool 1995' FNL, 2141' FWL, Sec. 18, T10N, R11W, SM Granite Point Field/Tyonek 12. Present well condition summary Total depth: measured 13934 feet Plugs (measured) true vertical 10811 feet ORIGINAL Effective depth: measured N/A feet Junk (measured) true vertical N/A feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 247 26" Driven 294 294 Surface 553 18" 1050 sx 600 600 Intermediate 3942 13-3/8" 668 sx 3989 3975 Production 6596 9-5/8" 8645 sx 6643 6616 Liner 5017 7" 9755 sx 11377 9906 2707 4-1/2" Slotted Liner 11215-13922 j~.,~ ~ ~. ~,, -~ 1~,., ~ Perforation depth: measured Slotted liner S EP 2 ~997 true vertical ~,laska .0it .& Was 60ns. Tubing (size, grade, and measured depth) 3-1/2", 9.2#, N-80 323' MD ' · 2-7/8, 6.4# N-80 10,407' MD Packers and SSSV (~pe and measured depth) Baker SC-1R pkr ~ 4987', Baker SAB pkr ~ 6459', Baker SC-2P pkr ~ 10364" MD Camco SCSSV ~ 323'. 13. A~achements Description summaw of proposal: x Detailed operations program: x BOP sketch: x "14. Estimated date for commencing operation 15. Status of well classification as: 8/29/97 16. If proposal well verbally approved: Oil: Gas: Suspended: Jack Har~ 8/29/1997 Name of approver Date approved Se~ice: X 17. I hereby certi~ that the foregoing is true and correct to the best of my_~nowledge. Signed: /E~ ~~' Title: Drilling Manager Date: 8/31/97 FOR COMMISSION USE ONLY Conditions of approval: Noti~ Commission so representative may witness IApproval No. Plug integri~.~ BOP Test ~ Location clearance__~I Mechanical Integri~ Test ~ Subsequent form required 10- ~ ¢ ~ 0 o,~° ~¢~ Original Signed By Oavid W. Johnston Approved by order of the Commissioner Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE KB =42.3' or 115' RKB from MSL __A B C D G RANITE~OINT PLATFORM WELL # 22~13 RDg2 PROPOSED COMPLETION SIZE WT CASING AND TUBING DETAIL GRADE CONN TOP BOTTOM 26" Inside Conductor 18" 13-3/8" 61 J-55 9-5/8" 40-43.5 N-80 Window Cut in 9-5/8" 7" 29 L-80 4-1/2" 12.6 3d~' 9~ BTC L-80 (Slotted) SC-BTC 47 294 47 600 47 3,989 47 9417 6,643 6,670 6,360 11,377 11,215 13,922 SC-B rc 423 JEWELRY DETAIL NO. DEPTH ITEM 1 289' 2 292' 3 4 6,469' Camco W/L SCSSV Nipple ID = 2.75" 3-1/T' Buttress X 2-7/8" Buttress Crossover Baker Locator Seal Assy with 14' of seals. F G H It ~TD = 13,934' MAX HOLE ANGLE = 83° Straddle Packer Assembly A B C D E F G H I J 9-5/8"x 7" Baker SC-tLR Retrievable Packer Mill-out extension 7" 29# L-80 Buttress Casing 5" 15 # L-80 Battress Casiug Seal-Bore K- Anchor 7"x 5" Baker SAB Permanent Packer Mill-out Extension X-Nipple (ID = 2.313") Wireline Re-entry Guide PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 11,490 11,530 C-5 4 5/28/96 11,550 11,570 C-5 4 5/28/96 ll,610 11,650 C-5 4 5/28/96 2-1/8" H,C. 2-1/8" H.C. 2-1/8" H.C. GRANIT~OINT PLATFORM WELL # 22-13 RDg2 FINAL COMPLETION 5/2/96 KB = 42.3' or 115' RKB fromMSL; FMC Wellhead B C CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 26" Inside Conductor 47 294 18" 47 600 13-3/8" 61 J-55 47 3,989 9-5/8" 40-43.5 N-80 47 9417 Window Cut in 9-5/8" 6,643 6,670 7" 29 L-80 BTC 6,360 11,377 4-1/2" 12.6 L-80 (slotted) TKC-LTC 11,215 13,922 ~4[2' 9~2 N~8{~ BTC 46 323 2~7/8' 6~5 N~g(~ SC~BTC 269 6~467 2~7/g~ ~45 N4~@ SC~B'IC 6~4~% D E F G 4,1I 1 J K L M N II TD = 13,934' MAX HOLE ANGLE = 73~ JEWELRY DETAIL NO. DEPTH ITEM 1 289' 2 292' 4 6,469' Camco W£L SCSSV Nipple ID = 2.75" 3-1/2" Buttress X 2-7/8" Buttress Crossover 5.5" OD Camco MMM GLM's w/RK latch: 2101', 3350', 4496', 5493', and 6203' Baker lx~ator Seal Assy with 14' of seals. A 4,982 B 4,993-6,266 C 6,266-6,453 D 6,454 E 6,455 F 6,459 G 6,466 H 6,471 I 6,487 K 10,364' L 10,325 M 10,373 N 10,407 9-5/8'x 7" Baker SC-!R Retrievable Packer 7" 29# L-80 Buttress Casing 5" 15 # L-80 Buttress Casing K- Anchor 7"x 5" Baker SAB Permanent Packer Mill-out Extension Ported NippLe 80-32 Baker Seal Bore Extension 4-1/2" x 2-7/8" Buttress Crossover 5~5" OD Camco MMM GLM's w/RK latch 6,867, 7,486, 8,3t7, 9,368, 10,268 7" Baker SC-2P Retrievable Packer 80-32 Seal-bore Extension X-Nipple (ID = 2.313") Wireline Re-entry Guide PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 11,490 11,530 C-5 4 5/28/96 2-1/8"H.C. 11,550 11,570 C~5 4 5/28/96 2-l/8"H.C. 11,610 11,650 C-5 4 5/28/96 2-1/8" H.C. Straddle Packer Assembly 12' FLOWI INE TO SHAKEFG RIG FLOOR 3.69' HYDRIL 13-5/8' SM ^NNUI. AR PREVENTE~ 4o5~ HYDRIL 13-5/s' 5M DUAL BOi= 13-5/8' 5M MUD CROSS 4-.85' 11 23.75' 13-5/8' 5M SINGLE BOP CELLAE 13-5/8' 5M HUB & FLANGE ABAFTER FLOOR .79' 18.82' 13-5/8" 5M HUB & FLANGE ABAPTER 1.22' CONDUCTOR 23.25' ~, 13-3/8' CSG GRANITE POINT 13-5/8' BOP GRASSROOT WELLS UNOCAL Granite Point Field GP #22-13RD2 Workover Procedure Revised 8/31/97 Revision #4 Objective: Convert GP 22-13RD2 to a 10,000 psi water injector. I. Skid Rig and Prepare for Workover: o Call-out FMC hand and pressure test wellhead and robing hanger. If the hanger or wellhead fail pressure test, prepare to mn the 13-5/8" 5M X 11" 1 OM tubing spool, 1 OM Adapter Flange. This equipment is being air freighted from Woodgroup Pressure Control in Lafayette. 2. Move rig from Leg #4 to Leg #3 and position well over Granite Point #22-13RD2 3. Bleed off gas from annulus. 4. Fill annulus with FIW. 5. MIRU slickline unit. e RU slickline lubricator and pressure test with water to 2,500 psi. 7. RIH and retrieve gas lift orifice from the Gas-lift Mandrel number # 1 ~ 10,285'. 8. Kill well by bullheading 100 BBLS of Filtered Inlet Water (FIW) down the robing. 9. Circulate through GLM #6 taking returns out the annulus through the choke. 10. Shut down. Isolate annulus from production and check well for flow. Ensure well is dead. Note: We will not be using a M-I Mud Engineer for this workover. Take all fluids to the grinding unit. Contact office before we discharge any fluids. If we discharge, a NPDES Discharge Log will need to be completed. 11. PU 10,500' of 3-1/2" Drillpipe. 12. Set BPV in tubing hanger and ND tree. NU 13-5/8" #13 Hub X 13-5/8" Flange XO spool and 13-5/8" BOPE. Note: BOP configuration from 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. 13. RIH and install FMC bore protector. RIH with FMC test plug. Test annular preventer to 250/3,500 psi and both pipe rams to 250/5,000psi. Test blind rams to 5,000 psi. GP 22-13rd2 WO proc 2.doc Page 1 of 6 09/02/97--9:32 AM UNOCAL Granite Point Field GP #22-13RD2 Workover Procedure Revised 8/31/97 Revision #4 II. Pull Existing Gas Lift Completion and Cut 5" Casing: 1. RIH and MU 3-1/2" landing joint. 2. PU and release tubing hanger and pull seal assembly out of seal-bore extension ~ 6,469'. 3. Circulate one complete tubing and casing volume with FIW. , POOH and laying down 3-1/2" tubing and jewelry. Check all tubing and jewelry for NORM. 5. RU Schlumberger wireline unit. 6. RIH with CCL and chemical cutter for 5" 15 lb/it to 6,453'. PULL CCL strip. Note: have jet cutter on location. 7. Spot cutter in the middle of a full casing joint right above K-Anchor. 8. Cut 5" 15-bl/ft casing. POOH with cutter. GP 22-13rd2 WO proc 2.doc Page 2 of 6 09/02/97--9:32 AM UNOCAL Granite Point Field GP #22-13RD2 Workover Procedure Revised 8/31/97 Revision #4 III. Retrieve Straddle Packer Completion and Production Packer: 1. RU GBR casing crew for 5" and 7" casing. e MU fishing BHA gl: Baker S-1 retrieving tool 4-3/4" Bowen Bumper Sub 4-3/4" Bowen Oil Jars 4-3/4" Drill Collars 4-3/4" Bowen Accelerator jars (Optional) Note: office Discuss the necessity ofjars, accelerators and bumper sub with fishing hand and prior to running--this goes for every BHA. . RIH stopping right above SC-IR packer to ~ 4,982'. Establish PU, slack-off, and torque values. 4. Circulate above packer to remove any debris. 5. Stab into packer. PU 18,000lbs over string weight and release packer. 6. POOH and lay down packer, 7" casing, and 5" casing. e MU fishing BHA#2: 4-1/32 spear to catch 5" 15 lb/fi casing and the ability to rotate to right. 4-3/4" Bowen Bumper Sub 4-3/4" Bowen Oil Jars 4-3/4" Drill Collars 4-3/4" Bowen Accelerator jars (Optional) o RIH with BHA#2 and establish PU, slack-off, and torque values. and stab spear into 5" casing stub. . PU and put spear in tension. Rotate 12-20 tums to the right and release K-Anchor from SAB permanent packer @ 6,455'. 10. POOH and LD packer. 11. MU fishing BHA #3: 6" OD Metal Muncher Packer Mill 4" Series 400 PRT tool with 3.875" Grapple 3 - 1/8" PRT Extension GP 22-13rd2 WO proc 2.doc Page 3 of 6 09/02/97--9:32 AM 12. 13. 14. 15. 16. 17. 18. UNOCAL Granite Point Field GP #22-13RD2 Workover Procedure Revised 8/31/97 Revision #4 3-1/2" Reg pin x 3-1/2" IF Pin x 3-1/8" PRT Bushing Three 4-3/4" Boot Baskets 4-3/4" Bowen Bumper Sub 4-3/4" Bowen Oil Jars 4-3/4" Drill Collars 4-3/4" Bowen Accelerator jars (Optional) R/H and mill SAB permanent packer ~ 6,455'. Note: be prepared to cut 2-7/8" tubing and overshot to fishing tubing and seal-bore extension. Circulate out any gas below SAB packer. POOH with SAB packer, 2-7/8" tubing and gas-lift mandrels. ~ fishing BHA Baker S-1 retrieving tool 4-3/4" Bowen Bumper Sub 4-3/4" Bowen Oil Jars 4-3/4" Drill Collars 4-3/4" Bowen Accelerator jars (Optional) RIH with BHA #4 stopping on top of SC-2P packer ~ 10,364' Circulate attempting to remove any debris on top of packer. Engage packer and retrieve. POOH and LD SC-2P. GP 22-13rd2 WO proc 2.doc Page 4 of 6 09/02/97--9:32 AM UNOCAL Granite Point Field GP #22-13RD2 Workover Procedure Revised 8/31/97 Revision g4 IV. Run Straddle Packer Assembly: Note: Spaceout so that the SAB packer will be above the SC-2P packer and the new SC- 1LR will be above the existing SC-IR packer assembly. Double check all OD's and ID's of all completion equipment to insure the water injection string can pass through. MU the following BHA: Shear-out sub One joint of 3-1/2" 9.2 lb/it Buttress tubing X-nipple (Id=2.813") One joint of 3-1/2" 9.2 lb/it Buttress tubing Mill-out extension BOT's 7"x5" SAB Permanent Packer K-Anchor Seal-Bore (4" OD and 20 ft long) Crossover 5" 15 lb/it Casing fi.om 6,200' to 10,250) 7" x 5" Crossover 7" 29 lb/it Casing Crossover Mill-out extension BOT's SC-1LR Retrievable Packer BOT's setting tool. 5" Drillpipe 2. RIH with BHA so that the SAB packer is 10,300'. 3. Obtain PU and slack-off weights. . Reverse circulate and spot corrosion inhibitor between straddle packer assembly and production casing. 5. Drop setting ball and allow to seat in shear-out sub. 6. Pressure up on drillpipe and set SAB packer. Continue to pressure up and shear-out ball. 7. Pressure up on annulus and attempt to test SAB packer to 1,500 psi. 8. Pressure up on drillpipe and set SC-1LR packer ~ 4,940'. 9. Pressure up on annulus and pressure test SC-1LR to 3,000 psi for 10 minutes. GP 22-13rd2 WO proc 2.doc Page 5 of 6 09/02/97--9:32 AM UNOCAL Granite Point Field GP #22-13RD2 Workover Procedure Revised 8/31/97 Revision #4 10. Release setting tool and POOH. V. Run Water Injection string. R/H with the Completion string as follows: BOT 80-32 Seal Assembly (18 f~ long, 4.0" OD, 3.0" ID) Crossover 3-1/2" 9.2 lb/fi Special Clearance Buttress tubing Note: Replace FMC tubing hanger elastomers 2. While circulating stab into SC-2P Packer ~ 10,300'. 3. Pressure up to 500 psi and test seals against the formation. 4. Pressure test annulus to 3,000 psi for 10 minutes. 5. Pull out of seals and spaceout. 6. Reverse circulate in corrosion inhibitor. 7. Spaceout so that the tubing has 10,000 lbs down on packer. 8. Land FMC tubing hanger. 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 22-13rd2 WO proc 2.doc Page 6 of 6 09/02/97--9:32 AM Unocal Energy' Resources D~'~'~ion 909 West 9th, P.O. BOX 1¢: Anchorage, AK 99519-6247 Telephone (909) 276-7600 Fax (907) 263-7828 UNOCAL Debra Childers Clerk DATA TRANSMITTAL 96-15 July 9, 1996 To: Howard Oakland 3001 Porcupine Anchorage, AK 99501 Alaska Oil & Gas From: Debra Chiiders 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal Transmitting the following items. Granite Point 22-13 RD ./blackline/film Completion Record, Run 1 5/28/96 . Granite Point AN-21 ~., blackline / film Completion Record, Run 1 6/04/96 ~ Granite Point AN-39 RD~ blackline / film Completion Record, Run 1 5/30/96 ~ MGS 17595'-31 ST2 /' blackline/film Completion Record, Run 1 6/26/96 - 'SCU 341-4 ~. blackline / film Completion Record, Run 1 5/11/96 ~4 SCU 341-4 ~ blackline/film Completion Record, Run 2 5/30/96 SCU 341-4 /' blackline / film TDT, Run 1 5/29/96 :(~ TBU G-26 ,/" blackline / film Completion Record, Run I 5/30/96 ~'~ TBU K-26 RD ,..-' blackline / film Completion Record, Run 1 6/09/96 TBU K-26 RD ,...~blackline / film Completion Record, Run 1 6/19/96 TBU K-26 RD -/ blackline/filmCompletion Record, Run 2 6/28/96 TBU K-3 RD v/ blackline/filmCompletion Record, Run I 6/21/96 'TBU M-2 S v" blackline / film TDT, Run 1 6/23/96 ~ TBU M-25 ../blackline/film Completion Record, Run I 6/21/96 rl TBU M-25 ¢ blackline/film Completion Record, Run I 6/25/96 TBU M-25 ./" blackline / film Completion Record, Run 3 6/27/96 ~'~ TBU M-5 ,/'" blackline/film TDT, Run I 6/22/96 . 6EIVED Please acknowledge 'receipt by signing and returning one copy of this transmittal or FAX to (907) ...- _ I Received by: I Date: tIUL ' - Alaska0il& Gas Cons. ~ An¢01age · ..... ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: x GAS: SUSPENDED: ABANDONED: SERVICE: 2. Name of Operator 7. Permit Number -~'=-'~-~:~ "'~. ~'~-:~96-75 Unocal 3. Address ~.F"';,,,~;~. ~ ,i_.~-~" ~ 8. APl Number P.O. Box 1~'247 Anchorage, AK 99519 '~'f~l~-~ ~,~ ) 9. Unit or Lease Name 4. Location of well at surface 2379' FNL & 1375' FWL, Sec. 13, T10N, R12W, SM Granite Point Field i 10. Well Number At Top Producing Interval At Total Depth '~ ~;~' '~- 11. Field and Pool 1995' FNL & 2141' FWL, Sec. 18, T10N, R11W, SM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Granite Point Field/Tyonek 115' RKB above MSLI ADL 18761 12. Date Spudded 13. Date T.D. Reached ' 14. Date Comp., Susp. orAband. I 15. Water Depth, if offshore I 16. No. of Completions 04/09196 05128196 I "05'/0'7¥~ ,.5'"/'~ ~/'~' 75 feet MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) I 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 13934/10811 N/A'1 Yes: x No:I 291 feet MD N/A 22. Type Electric or Other Logs Run VSI/CET 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 4-112" t2.6 L-80 11215 13922 6" Slotted Liner No Cement 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 1323 4987' MD 2-7/8" 6467 6459' 11490'-11530', 11550'-11570', 11610'-11650' 2-7/8" 6486-10406' 10364' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9974'-9995', 10003'-10016'; 10036'-10055' N/A 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 5/19/96I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 5/19/96 '24 TEST PERIOD => 44 62 124 N/AI 1409 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 80 750 24-HOUR RATE => 44 62 124 31.8 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NIARECEIVED Alaska 011 & Gas Cons. Comrrussion Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate r. 29. . 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top of Granite Point Sands (C-1) 9978 8995 C-2 .10528 9346 C-5 '11355 9893 Alaska 0il & ~-as Cons. CommJssJori Anchorage 31. LIST OF A'I-rACHMENTS Operations summary, Wellbore diagram,Directional Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~'~¢.~ C.a\ ~ '1-,le ~)A~ ~'rxz~A Date - j ¥' ~y , INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 GP 22-13 RD#2 CSG SIZE 26" 18" 13-3/8" 9-5/8" 7" 4-1/2" VVT/FT 61 40-43.5 29 12.6 GRADE J-55 N-80 L-80 L-80 TOP 47 47 47 47 6360 11215 BTM 294 6O0 3989 6670 11377 13992 HOLE SZE 17-1/2" 12-1/4" 8-1/2" 6 CEMENT DRIVEN 1050 SX 668 SX 8645 SX 675 SX SLOTTEDLINER RECEIVED JUN 1 2 1996 Alasks 011 & Oas Cons. Commission Anchorzg~ UNOCAL GRANITE POINT PLATFORM WELL # 22-13 RD#2 ACTUAL COMPLETION 5/2/96 KB = 42.3' or 115' RKB from MSL CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP 26" Inside Conductor 18" 13-3/8" 61 J-55 9-5/8" 40-43.5N-80 Window Cut in 9-5/8" 7" 29 L-80 4-1/2" 12.6 L-80 blank 4-1/2" 12.6 3-1/2" 9.2 2-7/8" 6.4 2-7/8" 6.4 BTC TKC-LTC L-80 slotted TKC-LTC N-80 BTC N-80 SC-BTC N-80 SC-BTC 47 47 47 47 6,643 6,360 11,215 11,184 46 324 6,486 BOTTOM 294 600 3,989 9417 6,670 11,377 12,753 13,922 323 6,467 10,406 TYONEK C-5 S/~ 9 10 11 12 13 14 15 ~TD = 13,934' MAX HOLE ANGLE = 73° JEWELRY DETAIL NO. DEPTH ITEM 1 291' Camco W/L Retrievable SCSSV Nipple: 2 323 3-1/2" Butt X 2-7/8" Butt Crossover 3 ...... 5.5" OD Camco MMM GLM's w/RK latch 2109', 3359', 4504', 5501', 6211', Straddle Packer Assembly 4 4,987' 9-5/8"x 7" Baker SC-1R Ret. Packer w/ Millout extension 5 4,993-6,266 7" 29# L-80 Butt Casing 6 6,267-6,453 5 # L-80 CSG between packers 7 6,455 Baker K Anchor 8 6,459 7"x 5" Baker Perm. SAB w/Millout Extensio 9 6,471 Baker Ported nipple (ID = 3.813") 10 6,471-6,486 Baker Seal Bore Extension 11 6,486 4-1/2" x 2-7/8" Crossover 12 ........ 5.5" OD Camco MMM GLM's w/RK latch 6880', 7498', 8329', 9381', 10280' 13 10,364' 7" Baker ret, SC-2P packer with seal-bore extension 14 10,374 HES X-Nipple 15 10,407 HES Wireline Re-~2 el D Minimum ID = 2.313"; Otis X-nipple Note: Gas flows through ported nipple TOP BTM Alaake, 0il & Gas Cons. Co~mia~on PERFORATION DArg~0rag0 ZONE SPF DATE COMMENTS SLOTTED LINER 11490 11530 C-5 11550 11570 C-5 11610 11650 C-5 5/28/96 2-1/8" H.C. 5/28/96 2-1/8" H.C. 5/28/96 2-1/8" H.C. O :~DRILL1NG\S CHEMATIC\GP\GPP\G2213R2A.DOC DRAWN BY: MWD 5/31/96 GRANITE POINT 22-13RD #2 DAY 1 (04~08~96) RECEIVED JUN 1 2 199G Alasl~ 0ti & G~s Cons. commission Anchorzge ACCEPT RIG @ 00:00 HRS ON 4/8/96. CONT RIG MODS. RIH & SET NEW 2-1/2" PX PLUG BODY IN X-NIPPLE @ 10,385'. SET PRONG IN BODY. F.L. @ 2750'. PRESSURE UP TBG TI1000 PSI, OK. HOLD TEST FOR 3 HRS FILL & BLEED OFF PRESSURE IN ANNULUS. RIH & OPEN SLIDING SLEEVE @ 10,293'. BRK. ClRC DWN TBG UP ANNULUS. SHUT IN ANNULUS & TEST PLUG, PACKER, CSG & SCAB TI2000 PSI TO 1975 PSI IN 30 MINS. DAY 2 (04/09/96) RU ON TREE AND PUMP DRY JOB AND CLEAN UP ANNULUS. SET BPU. ND FREE. SET BLANKING PLUG. NU BOPE. CHANGE OUT SAVER SUB AND RU TO TEST BOPE. TEST BOPE. OK. CHANGE OUT BAILS. DAY 3 (04/10/96) CHANGED OUT BALLS AND RU TO PULL TBG. PULL HGR TO FLOOR. CBU. NO FLOW. POOH W/PROD. TBG. STD BACK IN DERRICK AND LD ALL JEWELRY. RD TBG TOOLS. CHANGE TOP PIPE RAMS TO 5". TEST TOP RAMS, FLOOR VALVE, INSIDE BOP AND TOP DRIVE VALVES TO 250~5,000 PSI. SET WEAR BUSHING. MU BAKER PACKER RETRIEVING TOOL AND RIH W/BHA #1. DAY 4 (04/11/96) RIH W/BAKER RET. TOOL TO 6,294'. ENGAGE PKR AND PULLED LOOSE CBU. GAS AND OIL RETURNS AT BU. POOH W/PKR AND SCAB LINER. SEALS LOOKED LIKE THEY HAD BEEN PEELED BACK WHEN STABBING IN. DID NOT LOOK FLUID WASHED. MU BAKER 7" CPH PACKER W/EXTENSION AND 3 SETS OF TIW CHEVRON SEALS AND RIH. WORK SEALS INTO PBR AT 6,361'. TEST TO 400PSI. NO RETURNS F/ANNULUS. DROP SETTING BALL. SET PKR AT 6,348' W/3,500 PSI. TEST BACKSIDE TO 3,000PSI. BLED T/2925 PSI IN 30 MINUTES. NO RETURNS IN DP. PRESSURE TEST D.P. TO 3,000 PSI FOR 30 MINUTES. NO BLEED OFF. RELEASE F/PKR AND POOH. LD BHA #2. MU BHA #3 AND BEGIN PU 3-112" D.P. 22-13RD #2 PAGE2 RECEIVED DAY 5-7 (4/12 - 4/14/96) Aiask30il & Gas Cons. Commission Anchorage COMPLETE PU 3-1/2 D.P. AND CONT RIH W/PBR RETRIEVING TOOL. ENGAGE AND RELEASE PBR. POOH W/PBR. MU PACKER RET. TOOLS AND MILLING ASSY. AND RIH TO 10,340'. CHANGE WELL OVER TO 3% KCL/FIW. INJECT 9.5 PPG BRINE INTO GP 44-11. ENGAGE PACKER AND BEGIN MILLING PACKER. ATTEMPT TO MILL PAST BOTTOM SLIPS. UNABLE. PULL PACKER LOOSE AND CBU. WELL TAKING FLUID AT 20-25 BBL/HR. PUMPED LCM PILL (20 PPB LIQ. CSG AND 15 PPG MICA). BULLHEAD PAST D.S. PRESSURE INC. TO 2,800 PSI @ .75 BPM. POOH W/BHA. RECOVERED PKR AND TAILPIPE. RU SCHLUMBERGER AND RIH W/USIT TOOLS. WORK PAST 8,200' WLM. CONT TO 10,200'. USIT MOTOR WOULD NOT WORK. POOH. PIECES OF RUBBER AND METAL HUNG UP IN STABILIZERS. MU JUNKBSKT W/5.71" G.R. WELL TAKING 6-8 BPH. RECOVERED RUBBER AND METAL SHAVINGS. RIH W/USIT. TROUBLE GETTING TOOL CALIBRATION. RIH TO 11,215' AND LOGGED OUT. RIH W/1-11/16" SINKER BARS TO 11,690'. RIH WI3- 9/16" TBG CUTTER. CUT 4-1/2" SLOTTER LINER @ 11,679'. POOH AND RD S.W.S. MU WEATHERFORD PACKER MILLING ASSY. DAY 8 (04/15~96) RIH WI 6" MILLING ASSY. MILLED TIW "SS" LINER TOP PACKER FROM 11,209' - 11,212'. POOH RIH W/4 1/2" SPEAR. DAY 9 (04/16/96) RIH W/4-1/2" SPEAR AND ENGAGE 4-1/2" SLOTTED LINER AT 11,121'. PULL LOOSE. CBU. POOH. RECOVERED ENTIRE FISH: 462'. MU CLEANOUT ASSY AND RIH TO 11,377'. WASH DOWN. STOPPED @ 11,395'. WASH DOWN AND REAM F/ 11,395' - 11,643'. SET DWN SOLID. PUMP HIGH VIS SWEEP. DAY 10 (04/17~96) COMPLETE CIRC. OUT HIGH VIS SWEEP. CLEAN SAND. NO SIGNS OF WALL CAKE OR EMULSION. POOH W/C/OUT ASSY. PU 1,200' OF 2-7~8" TBG F/CMT PLUG STINGER AND RIH. CIRC @ 11,625 AND HOLD SAFETY MTG. MIX AND PUMP 45 BBLS OF 17 PPG CLASS G CMT. ClP @ 16:20 HRS. POOH. LID TBG. 22-13 RD #2 PAGE 3 DAY 11 (04/18/96) RECEIVED JUN 1 £ 1996 Aiask~ 0ii & Gas Cons. Commission Anchorage TEST BOPE. OK. PU CLEANOUT ASSY. RIH & TAG CEMENT @ 10,558'. C/OUT CEMENT F/10,558' - 11,334'. CBU. TEST CSG T/3,000PSl FOR 30 MIN W/NO LEAK-OFF. CLOUT CMT 11,334' 11,397'. TEST SHOE TO 3,000 PSI. LEAK OFF 687 PSI IN 15 MIN. HELD OBM SAFETY MEETING. CHANGE OVER T/OBM. CLEAN PITS & MONITOR WELL. DAY 12 -14 (4/19-21/96) PU KICK OFF ASSBY. SIDETRACK 6" HOLE @ 5 DEG/100 F/11,399' T/11,638'. POOH FOR BIT. DRILL 6" HOLE F/11,638'-12,036'. CBU. POOH TO SHOE W/NO PROBLEMS. PUMP DRY JOB. POOH FOR BIT. DAY 15 (4/22/96) POOH FOR BIT. RIH PU 12 JTS OF 3-1/2" DP. CSDL. CONT RIH. WASH & REAM 65' T/BTM. DRILL 6" HOLE F/12036'-12293'. DAY 16 (4/23/96) DRILL 6" HOLE W/MTR ASSY F/12293'-12575'. CBU & CHECK FOR FLOW, OK. POOH CHANGE BIT. DAY 17 (4/24/96) TEST MWD & MOTOR. PU 24 JTS OF 3-1/2" D.P. RIH T/12114'. BRIDGED. ATTEMPT TO WORK THROUGH. KELLY UP, WASH & REAM F/12089'-12120'. DRILL 6" HOLE F/12568'-12885'. (STRONG BUILDING TENDENCY). HOLE TAKING FLUID. 20 BBLS TOTAL. DAY 18 (4/25/96) DRILL 6" HOLE F/12885'-13059'. BIT HAD 21 HOURS/491'. CBU. POOH. PERFORM BOP TESTS. LID MOTOR. PU BHA & RIH. 22-13RD #2 PAGE 4 DAY 19 - 21 (4/26/96 - 4/28/96) COMPLETE RIH. DRILLING W/BIT #7 @ 13120'. TRIP IN THE HOLE WAS IN GOOD SHAPE. DRILL 6" HOLE F/ 13059'- 13566'. POH F/ BIT. RIH W/MOTOR ASSBY. DRILL 6" HOLE F/ 13566' - 13934' TD. CCH. POH & HUNG UP IN KEY SEAT @ 12292'- 12231'. WORKED LOOSE. POH FI CLEANOUT ASSBY. DAY 22 (4~29~96) CONT POH F1 CLEANOUT ASSBY. RIH W/ HOLE OPENER & 3 PT REAMER AS CLEANOUT ASSBY. REAMING HOLE TO 13934'. CCH. POH FI SLOTTED LINER. DAY 23 (4130196) RIH W/ 4-1/2" SLOTTED LINER TO 13934'. PU 12'. DROP BALL & RELEASE F/LINER, DAY 24 (5/1/96) POH. RIH W/2-3/8" CLEANOUT ASSBY. TAG TOL @ 11177' & COULD NOT WORK DOWN. POH. RIH W/ 2-3/8" MULE SHOED CLEANOUT ASSBY TO 13,898'. CHANGE WELL OVER TO #4 DIESEL. POH LD 2- 3/8" TUBING. DAY 25 (5~2~96) RIH W/PACKER ASSBY #1. SET & TEST PACKER #1 @ 10320'. POH, RIH W/PACKER #2. RECEIVED Alask~ 0ii & ~,~ 0OHS. Commission Anchorage 22-13RD #2 PAGE 5 DAY 26- 28 (5/3-5/96) A~hor~te RIH W/PACKER #2 AND 2 7/8" TUBING ASSY. STING INTO PACKER AT 10320'. TEST SEAL ASSY TO 500 PSI. PICK UP TO SPACE OUT LOST 20,000 LBS OF WEIGHT. POOH FOUND BAKER SC-2PAH PACKER HAD PARTED, DUE TO AN APPARENT ASSY. PROBLEM. RIH WI SPEAR RETRIEVE PACKER AND ASSY. LID TUBING THAT WAS DROPPED CHANGED OUT GAS LIFT VALVES IN CASE THERE WAS DAMAGE DUE TO THE DROP. RIH W/ PACKER ASSY. NO. 2. STING INTO PACKER AT 10,320' TEST SEALS TO 500 PSI. SET PACKER AT 6440' TEST PACKER TO 3000 PSI. R/U WIRELINE RETRIEVE ISOLATION SLEEVE FROM NIPPLE AT 6466'. SET PX PLU AT X NIPPLE AT 10,373' TEST TO 3000 PSI. RIH W/ PACKER ASSY. NO. 3. STING INTO PACKER AT 6,440' TEST SEALS TO 500 PSI. SET PACKER AT 6440' TEST PACKER TO 3000 PSI. POOH WITH RUNNING TOOL. DAY 29 (5/6/96) POOH P/U SEAL ASSY. , 2 718" TUBING AND GLM AND RIH. LAND HANGER TEST TUBING TO 3300 PSI WHILE TESTING ANNULUS TO 2900 PSI. N/D BOPE, N/U TREE DAY 30 (5/07/96) NIPPLE UP TREE & TEST TO 5000 PSI. CLEAN UP RIG & PUMP THRU EQUIP TO REMOVE OIL BASE FLUID. UNLOAD DIESEL F/WELL RIG RELEASED 2400 HRS 5/7/96. DAY 31 (5/08/96) UNLOAD 540 BBLS DIESEL F/ WELL. BLEED WELL PRESSURE TO 500 PSI & MONITOR F/8 HOURS, NO PRESSURE CHANGE. PUMP 30 BBLS DIESEL DOWN TUBING. REMOVE DUMMY SLEEVE F/SCSSSV. RIH TO PULL PRONG, SET DOWN @ 10312' (PLUG @ 10373') & UNABLE TO WORK DEEPER. RIH W/ 1-314" BAILER & SET DOWN @ 10320'. WORK BAILER TO 10328'. POH & RECOVERED HEAVY MUD. MOBILIZING COILED TUBING UNIT. 22-13RD #2 PAGE 6 DAY 70 (5/9/96) RIH TO SHOOT 11543'-11533', MISFIRE. PERFORATE HEMLOCK W/ 2-1/8" ENERJET GUNS @ 6 JSPF F/11543'-11533'; 11503'-11470'; 11448'-11415'; 11345'-11312'; 11233'-11200'; 11140'-11107'; 11030'- 10997'. RAN SHIFTING TOOL ON SLICK LINE TO OPEN "XD' SLEEVE AT 9172'. DAY 33 - 35 (5/10-12/96) RIH W/FISHING TOOLS ON 1-3/4" COIL TUBING. WASHING DOWN AT 10,328' TO PLUG AT 10,373. RECOVER DRILLING MUD AN FINE SOLIDS, LATCH AND PULL PRONG. ATTEMPT TO PULL PLUG BODY W/WlRELINE COULD NOT WORK PAST 7425' DUE TO BUILD UP ON TUBING. RIH W/ GS PULLING TOOL ON COIL TUBING LATCH AND PULL PLUG BODY .R/D COIL TUBING AND START GAS LIFTING WELL AT 20:00 HRS ON 5/11/96. CONTINUE TO TEST WELL SEE PRODUCTION REPORT FOR DETAILS DAY 36 (5/14/96) SKID RIG TO DO WIRELINE WORK ON WELL 11-24. PERFORM FLOWING PRESSURE SURVEY ON 11-24 WHILE ATTEMPTING TO FLOW 22-13 RD2. U- TUBING GAS VERY LITTLE FLUID ENTRY. RIH WITH 1 314" SLICKLINE BAILER. WORK THROUGH TUBING FROM 7560' TO 8320'. RIH TO 12,082' WHERE TOOL STOPPED DUE TO HIGH ANGLE. POOH VERY LITTLE RECOVERY NO BRIDGES PRESENT. R/U TO RUN PRESSURE SURVEY. DAY 37 (5/15/96) RAN PRESSURE GAUGES INTO 4 1/2" LINER TO 10,550'. PRESSURING UP GAS LIFT , GAS LIFT WELL RUNNING FLOWING SURVEY. PULL GAUGES OUT OF HOLE. DOWNLOAD DATA DAY 38 (5/16/96) SHUT WELL IN @ 15:30 HRS. PRESS TEST LUB. TO 1000 PSI, OK. RIH W/ELECTRONIC PRESSURE GAUGES ON PTA SLICKLINE. MADE 10 MIN STOPS @ 3408', 5551', 6930', 9430' AND 10550'. PRESSURE UP ANNULUS W/INJ GAS TO 1040 PSI. BEGIN FLOWING WELL @ 22:30 HRS. SAMPLE TRACE OF OIL @ 23:30 HRS. 22-13RD #2 PAGE 7 DAY 39 (5/16/96) FLOW WELL WITH PRESSURE GAUGES OUTSIDE TBG TAIL 10,550'. POOH AND MAKE STOPS AT 9430', 8329', 8200', 7582', 6970', 6261', 5551', 4554', 3408' 2167', AND O'. UNLOAD DATA FROM GAUGES . RD PTA SLU. CONT TO FLOW WELL THRU TEST SEPARATOR. DAY 40-41 (5/17-5/18/96) CONT. TO FLOW WELL. CHECKED CHLORIDES 8,000 PPM. (DWN FROM 10,000 PPM). PREPARE RIG FOR SHUT DWN. BLW DOWN BOILERS AND WATER LINES. DRAIN STEAM HEATERS. STORE TOOLS AND BEGIN TO TEAR DOWN PUMPS TO GREASE EXPENDABLE PARTS. SKID RIG OVER 22-13. GREASE FLUID END PUMP PARTS. COVER AIR INLETS TO EQUIPMENT. SECURE DRILLPIPE EQUIPMENT IN DERRICK. INJECT 98 BBLS OF WASTE FLUID AND FLUSH WITH 152 BBLS. RELEASE RIG AT 24:00 HRS ON 5118~96. LAST REPORT Day 42 (5/28/96) RU SCHLUMBERGER TO PERFORATE SLOTTED LINER. HELD PRE- JOB SAFETY MEETING. TEST LUB. TO 3,000 PSI. OK. RIH WITH 20'-- 2-1/8" DS HOLLOW CARRIER GUNS WITH 25A HD RDX, 0 PHASED , 4SPF PERF GUNS. MADE TIE-IN RUN. PERFORATED FOLLOWING INTERVALS: RUN 1 11630-11650 RUN 2 11610-11630 RUN 3 11550-11570 RUN 4 11510-11530 RUN 5 11490-11510 NO FLUID LEVEL. WORK THRU TITE SPOT @ 7450-8300'. PULLED 700 # OVER @ 8320' WHILE POOH. TITE @ 8700'-10300'. PULLED 650 # OVER @ 10270' WHILE POOH. NO FIND FLUID LEVEL. CLEAN RUN. NO FIND FLUID LEVEL. CLEAN RUN. NO FIND FLUID LEVEL. CLEAN RUN. TBG AND CSG PRESSURES REMAINED CONSTANT DURING ALL % GUN RUNS. RECEIVED JUN I 2_ 1996 Alask¢ 0ii & Cas Oo~';s. Commission Anchorage 22-13RD #2 PAGE 8 Day 43 (5/29/96) BEGIN FLOWING WELL @ 11:50 HRS. WELL TEST (24 HR RATES): 168 BFPD, 70 % CUT, %) BOPD, TBG PRESS = 100 PSI, CSG PRESS = 830 PSI. LAST REPORT RECEIVED JUN 1 2 1996 Alask~ 0il & Gas Cons. Commission Anchorage OPERATOF~ UNOCAL. '" Et::EYATt'ON~KB) ........ .: .............. ~ ........ -:t.'15 x SURFACE LOCA'r':[.ON ."-': 26:3407.'~0 Y SURFACE L. OCATION = ~,:~44,.,4~,,0 ............................ i_ . WELL : ;. API~ : ...... MEAS VER'T' SUBSEA iO0 t00. O0 i5. O0 .:. -::.-.: .. RECEIVED' Ananora~e 6'00 700 ......... 800" : 900 ~ .:.: · .t. 000 · ....~ itO0 / t200 ':::' ...... i:300 t400 .t500 ,..;'. .................. :, .. ::..:,. · t600 ::..:: 1'?00 · . :. :: .'L 800 -.. :- i900 · , 2000 : .:::,': .... . .,: 2100 · ' 2200 : ....... 2:3'00' ' 2400 : .i 2500 ,. 2600 270() 2800· 2900 . 5000 3i00 :::: ..'~ : .... 3200 , ..: :.~,,; 3400 ...... ~ :~500 ...:, ..... · : · ::g! . .... . .......... 200 200.00 ....... :300 ............. 2~-,~9' 400 399.92 500 4~?.24 POINT :~._.4=:.~o DATE:: JUNE:" ' ~,'. :i9~" ' :' ~ ~ ~I ~&?~. . : .. .' :. ..................................................................................... ~ ..................... ~ ....... : ............... J.: ....... · .................. '.,.: ........................ : ............................. : ......... : .... DR]:FT DR~FI' ~NGLE D[RECT~ON N(-S) E(-W) . 0, t2 -.~5, oo o., 35. N... 87,::7~; ~." '..~0:, 44" '" '-0., 47 . . -.ie4 ~.~e ............... (),-~ ........ :..--. .. s:~:~-~: ..... :-.-~o-~..: ............. ::,,,:~.::~.~ ................. : .......................... : ..... --384.24 7,1t N 54,37 E 578..'4'? -"483.47 "7,,0.~ N. '55;,5i9 E... ,: f5. t8 697.7~ --582 ,, 79 6.23 · N. '55 ~. 78"'.'E: ' 2 ~., 73 . . . ........ ~.._~ ............ ~ :.: . · ....,'. ~g_. ~ ..... · ...... ,~.~ ' ' ' ~?,-2~ ............-682'~ 2~t ...... ,~, ~ ~ 5~ ~ E ,,. 7,5~:~' 895 9t .... 781 9t 4 '75 N 50 35 E "~,~ cio ~6 . ~8 --881 . 58 4.66 N 47. ~2 E 38 . ~t 2~2'7 44,2'7 50,3f v~ '. .':" 4~ · · .' :'4,3.,.~0 :. ~6..'~, · '. · t076,24 -,~8i, 24 4. N 50,4~':..' E: :': '." · " tt95,87 -t080,87 4.83 ,N ~.~,'~7'. E :':..~.8~:74.'. · ...62:~i. :'.:.: ":' ::' ' ....... i.2e~-~-54 ..... i.-i.~)- ,. 54 ................ 4:er ............ :.~-~.~~-' ....:..'-':S4':;':~i~-::: ...... :: ..... ~-::~e-~--: ............ ::..: ..... '--.' .... ' i :3e~. 17 - i 2eo. i 7 4. e~ N ~0. '7e E ~. '7~ 75. ~ t494.8t '-t377.8i 4.92 N 50.~6 E 65.i3 82.57 : i5e4'.44. --t4Ve.44 4'.98 · '."N. 5'~.~.~.. E'." ....."..70':..~5 ': 8e,2V i6~4.06.-1579.06 5.00 .' .N..sii~2~:::E".'.'::"'.76:,O0". . ~6.04 ....... t"793,67 .... '-'t678'~-67 .............. S::'if ....... :':'-:":N~:'~-K%:"-U:'-tg~.~5~: ...... J:02,'90 t8~:3,27 '-t778~2'? .5.t6 N 50,5t. E 87,t. 5 J. 0~78 t~2.8~ -t87'7~86 5.22 N 4~.8~ E ~2.98 t16.70 2092.44 2t~2.0i 2490,70 -ie77 44 5,26 N . ' E .... 98:.,88, J. 2~,.~7 .. · -2077,0i 5,35 N ~&3. E.. · "i04.,87" ' ".i30'.72. --2~7~,~.~.'~ .............. 5:.~ ............ :.-~--4~-'~'-f_~ ........... i-~o:..~4-.:: ........... ~:.~:~-~).-.: ........................................... ~.~.?&.t4 5,3~ N 50,04 E it~,8& t44,~4 -2375.70 5.44 N 49.75 E i22.~6 i52.t7 2590 24 '"')a~ 24 5'.4~ N:4. ~9. E "' ~.- ..... 2689,78 -2574~78 5,49. N 49.40 .......... 2789, :32 ~.674.3,.~ .................. 5,5.~= ............ ~---,o,' ' ' ~ ""'r,~ 2888.86 -2773.86 5.46 N 50.t8 E i47.Si i8i.~0 2~88.40 -287J.40 5.45 N 50.'J5 E i5~.8~ t88.&4 :3087,95 -2972.95 ~..44 N..'50..;, 3t87.50' -3072.50 5.33' ...'N 5i.,~ :E..' ".,"!~5.90 203.26 .... 3~7 ,-07 .... -3 t"~-;'0~ ................. ~;"-~ ......... ~:~,-~~- 171 'z~ .............. ~,~J:O, ,.~ ............................. 3486,23 -3371,23 5 ~ 20 N 53,88 E i82 ~ 56 22~, 29 WELL~ : I)A'rE: JUNE 4, t'996 AF'I~ : CALCULATION : MINIMUM CURYA*rURE DRIFT ~RI.F'T ". '" ' .. · . . ME:AS VERT SLJBSEA ANGLE: D ~REcTZoN:' · N:(-.S ) .................................................................................................................... :.. _~ ..... ~ ......... · ............ ...' ;3600 3,.~8~ ,, 82 -3470. S2 : ,3700 ,3685.42 -,35'?0.42 `3800 ......... 37~'-104: ........ ~;36-70-i0-4~-- :'": ~3~00 ~884. ~8 -~'F~9.68 :.. 4000 ....... 5., i8 N 54 `` 51 E f87``'83 5 08 N 54,,?3 E .......... ,, .. ~ , · ... ~.). .. 4 83 N '.~,i ~:0 E' 208 ,, 44 39s4`` 34 -3$69.34 4·.,6`3 · ··N 4e·,,~2· E· ·: ................................................................................... :_.~_-..,,-;. ......... ;~ _~..;...z~,, ..... 4i00 4083.99 4200 4i83.60 '4300 ............4283'",28" 4400 4382.98 4500 4'482~68 ....................... -3968.99 4.9i N 5i``88 E 2i~.9.~, -4068.60 4.66. N 62~22 E 2i8.68 "~'41-~8-i~ ....... ~--:--= '.'N.:: 7:o ~..~:~. · E..'.....".:~ i.', f~9 -4267.98 4..~6 4600 4582~40 4700 4682.t. 3 4-800 ........ 4'78~;"86 .... 4~00 488t.'6t 5000 498i.38.'-4866.38 E: ( '--W ....... ;~, ~;.- ;&,.. ;;;. ....................................................... 232.60 23~. 88 · --:: ~4~..~,.~2 ..... . '.' .....:.~,,~'~". &5"' '"' 260 ~ ~28.64 5200 5i80~88 -5065~88 4~i4 N 68~3~ E .~..::~ "53~ ............... ~;$¢ ...... ~:'6~;'BO ....... 4...03 ' .N ..i~7 ~'g~.".E.',::': ::~..~45:~ 44. "' .'. · ~47~".¢i ...... :, .' : ...... 5400 5300,36 '.-s26s, 36 .3.., ~i'.''''' 'N:.'60.;::~:::~',.:..:; .:';:2~:~:~.1 .:..::: :: .3,~:4 ~"0~:.: '::".::'. :'.'.'. :;. ':;~:. ~:: '" :':' ::..:::~'00 'e~4eo, io .-~36~, io ,4, oe "'. N :t~O ~'.'~'::"~'.':':'..':,'..~2':~ :~Z ." '.':. ;: :~ Z~O:.~'.~ .."'.~.' .: .... ................................................................................................. ;2 ........ ~ ..... ~.:~.~ ..... '..'.. ;~_~ ............. ~--~ ...... L ...... ~;_..~.~;.: ........... ~_..: ..................... .... · ...... ~...~ ~: .... 5&O0 5579 8& -5464.8& J 8t N .. ..... 5700 5~79,63 -5564,63 5,78 N 50~46 E 260.2~ .... .... : ........... 50~ ...................... 5~";'~-'-:"~-~~';3~ .............. 4, i4 .~~'7 ,:~..' E'.'~.' '....:2~:.'~:~¢..' · '. ,.~:7:&'~3~; ...::..':~ .:. · .., s 'oo ': '"U.: :::.:..' ": "'::"'.:':. "::." ::" .:" '~iz~2_=~.~ .... ~._.~' · ': .~.x. · ~..i ........ 2L .:. :3'. ~;:....'.'. ;: ....... 2..:....._: ........ h .... .... :[:... 6100 6076.60 --596i.60 8.45 N 61.84 E 284..S2 4i0.78 6200 6i75.57 --606().5"F 7.99 N 6i~06 E 2~i.58 .,...; .: ................ .. .... :?. ~00 6~74'i'-~8 ......... ~~~--7,25 :.: '..N'..':.~'~'~".~'.:' :'E":'": '.'"::.':2'~:~ OG'":: ........ ::4~'~':.~.:~'~ .. :'....'....~ :.": .. · . ..... · :. . .:;~ .. ... ......... ........ ........ ... ::,:..: 6400 &373, e6 .--&25~. e6 6, 4e 'N ::57. i:.2~':..'E::..'.. · :":"...:..'"':".': 7' ' .":.: :~:?'.' ,: .. . 6~00 6473.37 '-~358.37 5,73' 'N 54.:~i. E :~!':0:;~6 :" 45`3,8~ ;:.";:. .......................................................................... :_.._:__: ...................... ~.:: .... : .............. ~..:;..~..~: . :- :....:. 6600 6572~8~ --6457.89 5~23 N 50.75 E 6700 6672 ~ 25 --655"Z. 25 7.68 N ~2 ~ 92 E 32i. 7~ 470. ~i · .. ~ ......... 60~ ........... 6~t-~tO',-8[~ ........ ~~"~3 ................5'~;~-w~ N .7~..0~.. E.. ...... .$27.~ g~ .. ' 45~ ~'~3 ..... · ..: · · : ; ........... ... ..... '"":::: 7000 6~64.6~ -.&84~.69 16.62 'N: 7&;3~[ E -:: ........................................................ ..._~._. ....... ~ ..................... ~ ......~ ......... ~ .............................. .................................................... : ........................ 7i00 7()5~.80 -&~44.80 i9.4i N 78~60 E 345.24 ,:.:: 7200 "2J. 53.3~ -7038.3~ 2i.~i N S2.5~ E: 3~O.~& 5~8.,40 : .............. 7~OO .............~2~';-~ .......... ~i~O ~'-5'~ .......... 2~, ~4 ......... ~- :~' ~"~' '. E' .. . :~54 ~.~. '.. · ~T ~,0~.. ~;.~,: · . ....... ..' ...... ''~. ~' ~ :' ·..:. : 7400 7336 , i5 -722i . i5 25.99 · ' ' N" 8&',.28": E'. · '" 357'. 7~ t)'?~ L 20' ~ . .. ' 7500 742~, 07 -'?~:iO. 07 28 ~ ~$0 N. 8~* 60' 'E.' · 359,2~ 724 ~ 87 . .. L. ................................................ ~ ........... [~_~._.~:_~ ....................................................................................................... .................................... j~,. ~:.' f.... ................................................................................................... .. .:. ,;. .. ~;~ ... . .... : -- .. . .:. .............. ........................................ ~ .......... -.~,_.:.~_~ ...... ~'__.-.z_.d ....... ~ ............ ~ .............. ..__' .......... · .......... : ............... ~.' ..... : ............ 3.80 ' · 266 `` `37 2'7~, · .E: .:"..' ~2.4.07 288.0 --4~67.68 4.28 ' 'N "~) ~ . · ......... · ·7,,. ~;T',:E'": ".'226,.43 2~5., 27 :, ................................................. ~.:__ "_.~: ...... ~_~ .... ~ .... ~_._.~_.~L~: ..... ~i..._..:~_i:..._L_..~ .......~ ..........=~...: ............... -44~7.40 4.~ N 7t.07 E 228.74 302.27 -4567,.i3 4.28 N 7i.,49 E 2~i,0'7 --~.6~6-~ ....... ~ 3.. 96 · - .. :N'.:.'Z.O.~.~':'.E:':. :'.'~....~' '~i'.~ ~ ~: · .........: .: .. · -47~. 6i 3,90 · ".N "6~ i ~7'"'E':'.:' "..~2~'75' ' .... 322 ~ ............ : ...... .- ' WE:LL ?. : GRANITE POINT 22-"'1:51BD2 DATE: JUNE 4, t99~ : 5073~20()5~502 CAI..CUI...A'rION : HINIHUH CURVATURE MEAS ~,.~ ~,..o.~,,,~,.~. · . . 7600 -/700 ........... ?800 ....... "?~00 8000 DRIFT VER'F 8UBSEA ANGLE DIR~C'T:KON N ( --.S ) E: ( .... W > - ..~ ;,~,;, .;.~r.~,~-~ ,+~ ............... .,.....~......, ,~.,...;. ............... ,~ a ~,'-.'~.z~-~ z.-;.-- --...~ ...... "'..~-..; ;-,~r;z.~'~;~'..,; '~,:,. .......... ;.'.:.'?.,. ..:," ~,;, ........... .~;;-~& ;..:-;;;; ...................................................... 75ti.85 -7396,85 3i,,.f~ S 88,,~J E ,~58.66 '7'74,5i 7,.,9,:~ ,. 73 -7480 ,, 73 ,'34. ,5'? $ 87 ,, 72 El ,-356.75 828.84 767.5 ~ 35' ........ ','-75~'i-;,-::~ ........ 57,8 i .~ 8'? ,,".'68 E'":· .~5~J4 ~,:38 .... -SE.T? ,, 88 .................................... 7753,45 ' --'76,.~8,, 45 4i,,i8 7827,,26 ' -7'?t2,,26 43;,63 '$' 87.~.:2&'.E ' ' .348 ~:44 t0i8,.'78 ......................................................................... : ...... .: ....... .:_~::_.~. ......... :__~ ..... '~=.::. .... ....................................................................................... t089. ',50 i 24O, 81{ i320. i 400.88 1482 ~ 66 i 565 ~ 68 8100 8200 8400 7897.83 -7782.83 46~55 ......... 8028'~2 ...... ~"f~X~i-3~---- 8087.ii -79'74.ii S 87 . 62 E 345 , L~(> S 88.04 E 342.48 · - '~' 88 ,.7.~,...E-' .....' :~40.34 .~,:~. .8~00 'Bi48,07 .-.8033,07 54', 4~ 'S. 8'?".:3a' E .... ...3;~5,06 ~. ...... --..,._-:J .......... L ..... ~ .....~- ' .......... "' ' :' ~- :'.' . .......... ~-~ .. ' :' 8600 8205,46 -8090,46 55 ~55 S 86,98 E .3~i , O0 · :"~ 8700 826i 06 -8i46.06 ~& ~3 S 87 ~ E 327.28 ?. eO00 '84t&, 08 -830t , 08 5B. ~26 ' · :'8~ :'8~ ;.'~",:'E":.' ...:320:;.3.~; iB22~ 3'7 i..~L..i._i.L~ ".: ...... ' _~..::.':: '~.~:L~L_: .................. 9 iO0 8469 . ~ 1 -83~4 . 9 i 56.05 N 8~ ~ 60 E 320 . i i i~06 . &2 ;':_; '~ 9200 8526~5 -84i1,~5 54.46 N 8~P~62 E 320.66 i988~75 ,i-:.' ' :'": 8645, ?i .'--8~30,7t. · 53.,'~9 .'." ':::'~"8B'~:~.~'~' .~."~;:.:':~.'~22,5i 2149~ 64 ". '" ' ' '~ "· :~. :'. .' ~ ....... J. ...... ~,~ .... 2 : . ~._~ ..~. ',,~,. ,, _~ .................................. 8765.34 --8650,34 52.74 N 8825.80 -87t0.80 52.88 N ........ 888~';"i~ ........ 8?Ti'-~-~ ........ 52,,82 · N 230~.86 2389.47 2627.75 2'706~25 2783.88 88.26 E 326.45 .88.05 E ~2~.02 .,~:~. ~:. E" ,;~ i, 5 ~. 9400 ~00 ¢?600 i:": 9700 :i ;-.. ......... .-'-9800' 9~00 : iO000 i .... i0t00 ~067.8t ..~8~54.8i 5i,4t N '88. i4 E :. i0200 ~i32.7~ '-~0i"Z,79 50.47 N 88.45 E ............ i-O~O0 ............. ~'i'83 ~~'~ .......... ~:, ~ .. .............. · :,~ ':~ ~ ~,': ,~:.,. ..~4.~..,:04 · 10400 926i, T2 -~Pi46,72 4~', i'~. .::'N '.8~ ~L,,. ' "· .... i0500 ~327, ~2 -92t2,52 48,48 ..? . :; ............................................. 8~46,,83 "-.883i,,83 52,,52 ' '.:"N ::88~?:':E · oo7. s,i -ems,2 s,i s2.. i i ""::: ' . · , .... I8 i. 20.:'iE: 336 09' 47.87 48,06 49.'30 N 89,2L~ E 350.92 N 89.05 E 35i.95 ~--:--N-:~? ~ [:..-. "$ '8~ ~8~ '" ....... ' ~ ,. . .."'. :..... ~:'~s .'. 3086,35 ::~21,:L t. i2 L~3Et6, ~P l 5462 ~ 09 ~ .I..~ '~' ~ 3688 ~ 29 3768, Z5 93~4,2'7 --9279.27 ~46i,23 ............... 9527-~ ...... 94i-2~-6~ ............ · 9~92,.89 -7477.8~ 96~8.13 -954~.i3 ?724.06 ~770,43 -~675.43 9~2i.02 -~806,02' ' ~'~80.52 354 ,. 52 354 ~ ~.t. 348.08 i0600 i0700 iO~O0 · . tt000 J. liO0 ti200 ,':i ......... ii~O0-'- i'i400 ':': it500 :'i .. ....... :::.:: :-. WELL : GRANITE POINT 22-i3RD2 DATE: JUNE 4, · ~ API~ : 5073,~2009502 CALCULATION : MINIHtJM CUAVATURE :': MEA8 VEAl.· SLJBSEA ANGLE: mD lmRE.C~I' ~ON m m mN ( .... S ) El ( '''W ) ..... ~,,~,~.~. . .....~.~,~ ...... · .... ~,, ~.~,~,,.~,,,~. . ............ ~.~;;~-~-~.. .............. ;~,~.;~ .~ ................... ~.~5~: ............................ ~;~,~:;.~; ......................................................... ~ ii600 i0031.60 --9916.60 62.0i S 83.48 E. ~38.2'7 385:.].66 .. ~"- ii?O0 100T7 ~ --~962.~3 6~ &O S 86.24 E ;.: ............ . .....: . · :. ii~O0 t0i52.87 -iOOLqT.8 70,Bi N :88,7¢ 'E "~26'.'47 .... 4'i2'?'~0r~ '" : ~ i2000 i0i84~3~ -iO0~.~ 72.48 "N '8'~'. E', · 33i~88 422t.~8 ~ .......... · ............................................ : .... ~=.._.'~ .... ~:~ .......... ~.~_~.~,,3 ......... ~ ........ =......._ ~ .......... :.~.~.= .......... .;._..,: ._.,~ ............... %....,: ...... ~...: ~,.. i2100 i02i2.02 -iO0~'?.O 75.49 N 64~50 E ~4i.i4 43i7.2i ' i2200 i02~&.20 -i0i2i.2 7&.45 N 8~.i0 E ~ ~.' ........ i-.2300 ............... t02~-~3 ........-i 0~:-45-z? ........ ~-;~ .......... ~~-~:~--:'---~?;~ ....... ~';.~ .................................... F,d · · .'', ' . ...... :' .... . .... . ...... ,. · ..: ..... t O~i 7.84 -i 0202,8 72, O~ N :88 ~ ~" 'E' ' .'.": ~2'. 06 4702 , triO ~..~ 12500 ... i'"": i2600 i' 12700 i037~,00 .....' ........... i2800 ......... ~'0~i~2.' ;-'78' .~: i2900 i0450,38 :' i3000 i04~0,7t ~'~ ................................ ~{...! ~ 13100 :::':'i 13200 i056&,04 t~O0 t0668.9:0 ........................................... :7 .-: ! 13700 10733.02 i...,.. .. · ........... t-~800 ..... ............. . 2~ ................ ':j... .~. · . ........ i~' ' ~.. ~.:.: .. ................. [. -10233,3 72,44 N 88,3t E 354,~ -- f 0264,0 7 i ~ 77 N 87 ~ 79 E .35'?, 88 4892 ~ 82 .......... ...... :- .... ............................. ""i0~5.~ 67.22 '.".: ' "" ': .... '"" ...... : " ' =' '~ =' ""~ .N 85. ~. E .... ~&8. ,~ ,,079..,,.,;~. -t0~'75.7 '65.25 · .. ' N '85.24'..'E. · .'.'..'~T5~, 8'4. :": :'. :.5i~0.'.:'.4'2:. ' "'. ::: ". ~. '." ............................................ · _..~: .......... LLL_Lz_LL.iL.:_~,~&?.: .' ~:_,~:.:.:..~ ..... "; ....... : ....... · ................... '...._.L ..... .,._..~ ........... --i045i,0 "/~.,i~ N 89~4~ E ~82,i~ 5:555,3~ '-~:0484'~ 8 ............ ~~:--? :N -.. ~i'7~..E.:~ :...:. '.'~G.2~ 7~ --~~'~ -i0520~2 .&~,'2& ' .'"S ':8~i~:'~E:'~:.'::~8:~'~:55 · ,. ~4~.,0t ..... :.. .. 2 .......... ~ ......... :. ~ ~. ~2_:, ~.~ .... r_.2~ ~.' 2,_.: _::.....~,x:...:2.~:.~: .:_ .:'.: L .2..:~_ :~ 5:.~., :: ...... ' .... --i 0585, ~ 7 i , 82 ~ 88, O~ E ~78 , 2i 5'7~i , 96 - i 06i8,0 70, ~9 N 89 ~ O0 E 3'77,5~ 582~ ~ 5 t .......... i0T'~:-33- ....... ~-~~ 3 7~.,-~7 .,' ~ .~, ~':' E,...:......$:F~:~'.4'~ ...... ::." :5'~2G:~.7'&' . ...' ........: : . io7~.e2 -lO6e4.8 70.20 ..' '..:a '::eei :~.: :z.:::. :.::..sei'~5.."..."..60i:~::.~ .. :..'.. ...... .'. : · : t0~tt ,Z4 -i06 6.Z 70..'20 .'. ' ::: ::'.. '" .:' :,".: · '. ':5 ~ '..2~..'.' ......... ...................................................... 2 ....... : ................................. :..2:..~.;~...:~,:~:'22,:..~:2...~.~2 ..... ~L2,..5;,~.~.:~'~.', :..~:~..::..:.~ ............................................................... · . .. .. ~; . :'.. "' ::. : :. · .. . .. ... . . ., . ...... .... : .... .. . '..... . ..... .: .... . .' . :. . : .. · .. · ........ · ~ : .... .'. ....... .. .... . . . ..... .'~ .. . · .:. · . .... · · :.. . .. · . '"" 22 ....... : ............ z,._..~ .....2,.~_~_2.2 ..................... .iz._.~: ~2 ............................. : ............. ~ ..................... :4: ':; ....................... ................... 3LASKA OIL AND GAS CONSERVATION TONY KNOWLE$, GOVEBNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 17, 1996 G. Russell Schmidt, Drilling Manager Union Oil Company of California (UNOCAL) P O Box 196247 Anchorage, AK 99519 Re: Granite Point Field 22'13RD #2 UNOCAL Permit No 96-075 SurfLoc. 2379'FNL, 1375'FWL, Sec. 13, T10N, R12W, SM Btmhole Loc. 1562'FNL, 1989'FWL, Sec. 18, T10N, RllW, SM Dear Mr. Schmidt: Enclosed is the approved application for permit to re-drill the above referenced welt. The permit to re-drill does not exempt you from obtaining addkional permits required by law from other governmental agencies, and does not authorize conducting re-drilling operations until ali other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) ofthe BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission at 279-1433. BY ORDER OF THE COMM~SION dlf/encl c: Dept ofFish & Game, Habitat Section- w/o encl Dept of Environmental Conservation- w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION ~OMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill: Redrill: x I lb. Type of well Exploratory: Stratigraphic Test: Development Oil: x Re-Entry: Deepen:I Service: Developement Gas: Single Zone: Multiple Zone: 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Union Oil Company of California (UNOCAL) 115' RKB above MSL Granite Point Field 3. Address 6. Property Designation P.O. Box 196247 Anchorage, AK 99519 ADL 18761 4. Location of well at surface Granite Point Platform 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2379' FNL & 1375' FWL, Sec. 13, T10N, R12W, SM Granite Point Field ~,K Statewide Oil 8, Gas Bond At top of productive interval 8. Well number Number 2025' FNL, 357' FEL, Sec. 13, T10N, R12W, SM 22-13RD #2 U62-9269 At total depth 9. Approximate spud date Amount 1562' FNL, 1989' FWL, Sec. 18, T1 ON, R1 l W. SM April 11, 1996 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3100 feet 369 feet 5089 13,943, 10,817' feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.O35 (e)(2)) Kickoff depth: 13400 feet Maximum hole angle: 70 Maximum surface 1480 psig At total depth ('rVD) 1650 psig 18. Casing program Setting Depth size Specifications Top I Bottom Quantity of cement Hole I Casing WeightI Grade I coupling I Length MD I TVDI MD I TVD (include stagedata) 6 4-1/2 12.6 L-80 Butt 2728' 11215 9865 13943 10817 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summaryRECEIVED Total depth: measured 13821 feet Plugs (measured) Grot Plug 11,377'-11,877' true vertical 10689 feet APR 0 9 199~ Effective depth: measured 13731 feet Junk (measured) true vertical 10660 feet Alaska 0it & Gas Cons, Commission Anchorage Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 247 26" Driven 294 294 Surface 553 18" 1050 sx 600 600 Intermediate 3942 13-3/8" 668 sx 3989 3975 Production 9370 9-5/8" 8645 sx 9417 8653 Liner 5017 7" 9755 sx 11377 9906 1538 4-t/2" Slotted Liner 12753 10350 978 3-1/2" Slotted Liner 13731 10660 Perforation depth: measured Slotted Liner true vertical 20. Attachments: Filing fee: x Property Plat: x BOP Sketch: x Diverter Sketch: Drilling program: x Drilling fluid program: Time vs. depth plot: x Refraction analysis: Seabed report: 20 AAC 25.050 requirements: 21. I herby certify that the foregoing is~r~e ~y~d correct ta ti~ b~t of..m,y:~Ce, owledge: Signed: G. Russell Schmidt .f.,,~L.~Y~,~.J~.~tl-e: DdllJng Manager Date: April 3, 1996 Commission Use Only Permit Number I APl number , Approval date. I See cover letter -O:Z.~. -/ ~' / '/' ~" for other requirements Conditions of approval Samples required: [ ] Yes ~]'No Mud log required: [ ] Yes ~No Hydrogen sulfide measures [ ] Yes '[;x]'No Directional survey required ~ Yes [ ] No Required working pressure forBOPE [ ]2M; J~3M; [ ]5M; [ ]10M; [ ]15M Other: Original Signed By David W. Johnston by order of _ Approved by Commissioner the Commission Date: ; , Form 10-401 Rev. 12-1-85 Submit in triplicate GP 22-13 Redrill #2: Preliminary Procedure 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 MIRU Rig. Open sliding sleeve. Kill well with OBM Set BPV, ND Tree, and NU BOPE. Test BOPE POOH with existing Completion MU BHA~I RIH and Retrieve scab liner. POOH MU BHA #2 RIH and install Liner Top Packer POOH RU Schlumberger and run CSG inspection log. MU BHA #2B RIH and retrieve PBR from MHS packer. POOH MU BHA #3 RIH and mill up and retrieve MHS packer POOH MU BHA #4 RIH and mill up liner hanger POOH RIH with casing cutter on wireline and cut 4-1/2" slottted liner 500' below 7" shoe. POOH and RD wireline MU BHA #5 RIH with spear and retrieve 4-1/2" slotted liner. MU BHA #6 RIH with cement String Lay cement kickoff plug. Drill Sidetrack with 8.4 PPG oil-based mud. TD ~ 13934' MD. Run slotted liner. Cleanout liner. POOH. Run straddle packer assembly to isolate 9-5/8" X 7" liner lap. Complete well. ND BOPE and NU Tree. Release Rig. 11,000.00 11,500.00 12,000.00 12,500.00 13,000.00 13,500.00 14,000.00 GP 22-13 RD#2 Depth vs. Days 20 Days ~ RD#2 Estimated Depth -'--'RD#2 Actual Depth ~. RD#1 Actual Depth RE E iVE 0 9 1996 lsska Oil & as Cons. Corn nchornge ~ission DPVSTIME.XLS RD#2 Chart 4/4/96 UNOCAL( ) KB = 42.3' 5-8 GRANI', E POINT PLATFORM WELL # 22-13 RD ACTUAL COMPLETION AS OF 2/27/96 SIZE WT CASING AND TUBING DETAIL GRADE CONN TOP BOTTOM 26" Inside Conductor 47 294 18" 47 600 13-3/8" 61 J-55 47 3,989 9-5/8" 40-43.5 N-80 47 9417 Window Cut in 9-5/8" 6,643 6,670 Baker SC-IR PKR and TIW Seal Assy. 6,287 6,368 WITH 1 JT of 7" 29# CSG between. 7" 29 L-80 BTC 6,360 11,377 4-1/2" 12.6 L-80 SC-BTC 11,215 12,753 3-1/2" 9.2 J-55/N-80 SC-BTC 12,753 13,731 NOTE: 4-1/2" and 3-1/2" = slotted liner Tubing 3-1/2" 9.2 N-80 BTC 42.3 2-7/8" 6.4 N-80 SC BTC 331.9 268 10.407 JEWELRY DETAIL NO. DEPTH ITEM 1 268' 2 303' 4 10,293' 5 10,335' 6 10,338' 7 10,342' 8 10,364' 9 10,385' 10 10,407 Camco W/L Retrievable SCSSV Nipple: ID = 2.750" 3-1/2" X 2-7/8" XO ID = 2.378" 5.5" OD MMM GLM's w/RK Latch 1,991', 3,267', 4,411', 5,424', 6,160', 4.75" OD KBMM GLM's 6,800', 7,438', 8,239', 9,327', 10,254' I-lES XU Durasleeve ID = 2.313" No Go Locator Top of PBR Ratchlatch Seal umt HES MHS Packer "X" Profile Nipple Wirelme Re-entry Guide/Pump out Plug TYONEK C-5 SAND PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS SLOTTED LINER TI} = 13,821' MAX HOLE ANGLE = 83° O :~DRILLING\S CHEMATIC~GP\GPl~G2213RF2.DOC DRAWN BY: MWD UNOCAL ) GRANi', E POINT PLATFORM WELL # 22-13 RD PROPOSED ABANDONMENT KB = 42.3' or 115' RKB from MSL ~: ....... " .................. 222-_ .z '-?-'3;::---':-::i--:~ ...... Illl] Ill \ / Ill 11,327' T.O.C. 11,877' Cut 4-1/2" Slotted Liner TYONEK C-5 SAND TI} = 13,821' MAX HOLE ANGLE = 83° O 5DRILLINGkq CHEMATICSGP\GPP\G2213ABD.DOC CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 26" Inside Conductor 47 18" 47 13-3/8" 61 J-55 47 9-5/8" 4043.5N-80 47 Window Cut m 9-5/8" 6.643 Baker CPH Liner Top Packer 6.350 7" 29 L-80 BTC 6.360 4-1/2" 12.6 L-80 SC-BTC 11,215 3-1/2" 9.2 J-55/N-80 SC-BTC 12,753 NOTE: 4-1/2" and 3-1/2" = slotted liner 294 600 3,989 9417 6,670 6,360 11,377 12,753 13,731 Cement Plug: 11,327' to 11,877' Abandon slotted liner and provide kick- off plug for Redrill #2. JEWELRY DETAIL NO. DEPTH ITEM _. ~¢. 0oa~'~xss\os _., ~. 6ss co°!~°.~',¢, DRAWN BY: MWD ik\s.SV'*'-" 9xx '- i~,,~c..,'o"o'~ o.~ 4/4/96 SLOTYED LINER PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS UNOCAL KB = 42.3' or 115' RKB from MSL GRANh ~ POINT PLATFORM WELL # 22-13 RD#2 PROPOSED COMPLETION 3/4/96 CASING AND TUBING DETAIL SIZE WT GRADE . CONN TOP BOTTOM 26" Inside Conductor 18" 13-3/8" 61 J-55 9-5/8" 40-43.5 N-80 Window Cut in 9-5/8" 7" 29 L-80 4-1/2" 12.6 L-80 3-1/2" 9.2 J-55/N-80 BTC SC-BTC SC-BTC 47 294 47 600 47 3,989 47 9417 6,643 6,670 6,360 11,377 11,215 12,753 12,753 13,731 NOTE: 4-1/2" and 3-1/2''= slotted liner 3-1/2" 9.2 N-80 BTC 42.3 268 2-7/8" 6.4 N-80 SC-BTC 269 6,435 2-7/8" 6.4 N-80 SC-BTC 6,450 10,407 5 JEWELRY DETAIL NO.; DEPTH ITEM 1 268Y Camco W/L Retrievable SCSSV Nipple: 5.5" OD Camco MMM BLM's w/RK latch 8 9 10 11 12 TYONEK C-5 SAND TD = 13,821' Straddle Packer Assembly, 3 6350' 9-5/8"x 7" Baker SC-IR Ret. Packer 4 . 5" 15 # L-80 CSG between packers 5 64'30' 7"x 5" Baker SC-2PAH w/Ret. Extension 6 Baker CMU sliding sleeve 7 Baker Seal Bore Extension 8 4-1/2" x 2-7/8" XO Sub 9 5.5" OD Camco MMM BLM's w/RK latch 10 10,364' 7" Baker ret, packer with seal-bore extension 11 X-Nipple 12 Wireline Re-entry Guide i~ ~ C ~ i~i ~ TOP BTM PE~O~TION DATA ZONE SPF DATE COMMENTS SLffI~rED LDI'ER MAX HOLE ANGLE = 83° O:kDRILLING\SCHEMATIC\GP\GPP\G2213R2P.DOC DRAWN BY: MWD 4/8/96 RT 114.75' RIG] 47' '5.75' 62' 75' (40' CML) WELLHEAD STAR'IS HERE PROD DECK 26" @ 294' RKB ,~ (105' BML) TOP OF LEG (75' WATER DEPTH) SEA LEVEL (MLLW) Top 26" (~ 177' RKB (only on 3 Inner eondu~tom) MUD LINE Note: Outer 9 conductors have 26" t~ck to surface Inner 3 a/ots are d/f/erent. See attached plan view. GRANITE POINT WEI I RORE CONDUCTOR STATUS UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: CLL Filet GPCOND. clrw DATE: 07-21-95 ~ANITE PT 1 ~13RD 31-13 22-13 LATFORM 24-1.TM 33-13 + 24-13RD + 38 + + 50 kDL 18742 Sec. 18, T. 10 N, R. 11 W 18761 22-13RDST1 22-13RD ~ Prop. Loc. GP 22-13 ALASKA B]~ION UNOCAL~ Granite Point Field PROPOSED GP 22-13RD2 ~ BY B.L. S'I~ABT DI~I~D~D BY DAT~ ~ 4, 1996 SCALE lIN= IO00FT COOK DATUM MI~W CALC. MEI'HOD EAI)IUS OF CUBV. J tx~x I I I ecl 33 131793 Well Pat~t ..... L_ ......... I_ ......... L .... I 22 Tie in at 11,400[ MD Build aL 5 deg/~00 ~ Cb CD /qb Cb Cb CD CD 33 13RD to 11,738 MD Hold angle aL ?(I).5 deg to 22 ISR Point il~e on !End of Build }End of Turn [End of Hold UNOCAL ~$tructure : GRANITE POINT Platform Well : 22-13Rd Field : Granite Point Field Location : Cook Inlet, Aloska WELL PROFILE DATA MD Inc Dir WD Nodh East Deg/lOOj 11400 53.56 D2.03 9921 552 3688 0.00 11739 70.50 92.50 10079 540 3986 5.00 12069 70.50 Eg.0O 10189 336 4298 1.00 13943 70.50 ~9.00 10815 367 6064 0.00 !Creot~d by : jones For: iDate plotted : 4-Apr-96 Plot Referer~ce is 22-13 Rdl~3 Versk~ ~3. , [Coordinotes are in feet reference slot ill3-2. True Verficol Depths ore reference RKB (R~ ~156).I Scole 1 ' 75,00 E a s f - - > 5600 3750 3900 4050 ~200 4350 4500 4650 4800 4950 5100 5250 54~) 5550 5700 5850 6000 61 50 N 89 DEG E 60?0' (TO TD) · **PLANE OF PROPOSAL*** 90O _75O _600 - _450 - _300 _ 9750 _ .. 9900 _ 10050_ 10200_ 10350_ 10500_ 10650_ I V 10800_ I0950_ 11100 .00 TD LOCATION 2012' FNL, 2160' FEL SEC.7,TION,RllW · KOP - Sidetroc~ Pt Ar~le Build 70.49 AVERAGE ANGLE ' 70.5 DEG ''' "" ~'~':~, I I I I I I I ~ I I I I I I I I I I I -I I I I I I I I I I I I I 1 I I I I I 3450 5600 5750 3900 z050 4200 4550 4500 4650 4800 4950 51 O0 5250 5400 5550 5700 5850 6000 6150 6300 Scale 1 ' 75.00 Vertical Section on 89.00 azimuth with reference 0,00 N, 0.00 E from slot #..z-2 UNOCAL GRANITE POINT PLatform 22-13Rd slot ~3-2 Granite Point Field Cook Inlet, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : 22-13 Rd~3 Version #3 Our ref : prop1579 License : Date printed : 4-Apr-96 Date created : 21-Mar-96 Last revised : 4-Apr-96 Field is centred on n60 59 36.T51,w151 18 33.112 Structure is centred on n60 57 52.745,w151 20 20.066 Slot location is n60 57 29.311,w151 19 52.203 Slot Grid coordinates are N 2544550.000, E 263409.000 Slot local coordinates are 2379.66 S 1375.79 E Reference North is True North UNOCAL GRANITE POINT Ptatform,22-13Rd Granite Point Field,Cook Inlet, ALaska PROPOSAL LISTING Page 1 Your ref : 22-13 Rd~ Version #3 Last revised : 4-Apr-96 Heasured Inc[in. Azimuth True Vert. R E C T A N G U L A E Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D ! N A T E S Deg/lOOFt Sect 11400.00 53.56 92.03 9920.75 352.30 N 3688.56 E 0.00 11500.00 58.56 92.18 9976.57 349.25 N 3771.44 E 5.00 11600.00 63.55 92.32 10024.96 345.81 N 3858.85 E 5.00 11700.00 68.55 92.45 10065.53 342.00 N 3950.13 E 5.00 11738.96 70.50 92.50 10079.16 340.42 N 3986.60 E 5.00 3694.15 KOP - Sidetrack Pt 3776.96 3864.30 3955.50 3991.93 End Angle Build 11800.00 70.49 91.85 10099.54 338.24 N 4044.09 E 1.00 11900.00 70.49 90.79 10132.93 336.06 N 4138.32 E 1.00 12000.00 70.49 89.7'5 10166.32 335.6~ N 4232.58 E 1.00 12068.88 70.50 89.00 10189.32 336.35 N 4297.51 E 1.00 12500.00 70.50 89.00 10333.23 343.44 N 4703.84 E 0.00 4049.38 4143.56 4237.80 4302.72 End of Turn 4709.11 13000.00 70.50 89.00 10500.13 351.67 N 5175.08 E 0.00 13500.00 70.50 89.00 10667.04 359.90 N 5646.33 E 0.00 13943.26 70.50 89.00 10815.00 367.19 N 6064.11 E 0.00 5180.43 5651.75 6069.59 TD ALL data is in feet unless otherwise stated Coordinates from slot g3-2 and TVO from Rl(B (Rig #156) (115.00 Ft above mean sea Level). Vertical section is from wellhead on azimuth 89.00 degrees. Declination is 0.00 degrees, Convergence is -1.17 degrees. Calculation uses the minimu~ curvature method. Presented by Baker Hughes !NTEQ UNOCAL GRANITE POINT Platform,22-13Rd Granite Point Field,Cook Inlet, Alaska PROPOSAL LISTING Page 2 Your ref : 22-13 Rd~r5 Version Last revised : 4-Apr-96 Comments in we[[path MD TVD Rectangular Coords. ConTnent 11400.00 9920.75 352.30 N 3688.56 E KOP - Sidetrack Pt 11738.96 10079.16 340.42 N 3986.60 E End Angle Build 12068.88 10189.32 336.35 N 4297.51E End of Turn 13943.26 10815.00 367.19 N 6064.11E TD Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a 9920.75 352.30N 3688.56E n/a 9920.75 352.30N 3688.56E 9 5/8" Casing n/a 9920.75 352.30N 3688.56E n/a 9920.75 352.30N 3688.56E 7" Casing Targets associated with this wel[path Target name Position T.V.D. Local rectangular coords. Date revised 22-13 Rd~3 (1)26-Mar 267695.000,2544797.000,0.000010168.00 334.53N 4280.21E 21-Mar-96 22-13 Rd~3 (2)26-Mar 269467.000,2544790.000,0.000010815.00 363.73N 6052.05E 21-Mar-96 All data is in feet unless otherwise stated Coordinates from slot #3-2 and TVO from RKB (Rig #156) (115.00 Ft above mean sea [ever). Bottom hole distance is 6075.21 on azimuth 86.53 degrees from wellhead. Total Dogleg for we[[path is 20.25 degrees. Vertical section is from wellhead on azimuth 89.00 degrees. Declination is 0.00 degrees, Convergence is -1.17 degrees. Calculation uses the minim~ curvature method. Presented by Baker Hughes INTEQ UNOCAL GRANITE POINT Platform,22-13Rd Granite Point Field,Cook InLet, ALaska PROPOSAL LISTING Page 1 Your ref : 22-13 Rd~r5 Version #3 Last revised : 4-Apr-96 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 11400.00 53.56 92.03 9920.75 2027.35 S 5064.35 E 0.00 11500.00 58.56 92.18 9976.57 2030.40 S 5147.22 E 5.00 11600.00 63.55 92.32 10024.96 2033.85 S 5234.64 E 5.00 11700.00 68.55 92.45 10065.53 2037.66 S 5325.92 E 5.00 11738.96 70.50 92.50 10079.16 2039.23 S 5362.38 E 5.00 3694.15 KOP - Sidetrack Pt 3776.96 3864.30 3955.50 3991.93 End Angle Build 11800.00 70.49 91.85 10099.54 2041.42 S 5419.88 E 1.00 11900.00 70.49 90.79 10132.93 2043.59 S 5514.11 E 1.00 12000.00 70.49 89.73 10166.32 2044.02 S 5608.37 E 1.00 12068.88 70.50 89.00 10189.32 2043.30 S 5673.30 E 1.00 12500.00 70.50 89.00 10333.2~ 2036.21 S 6079.62 E 0.00 4049.38 4143.56 4237.80 4302.72 End of Turn 4709.11 13000.00 70.50 89.00 10500.13 2027.99 S 6550.87 E 0.00 13500.00 70.50 89.00 10667.04 2019.76 S 7022.12 E 0.00 13943.26 70.50 89.00 10815.00 2012.47 S 7439.89 E 0.00 5180.43 5651.75 6069.59 TD AL[ data is in feet unless otherwise stated Coordinates from NW Corner of Sec. 13, TION, R12W SM and TVD from RKB (Rig #156) (115.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 89.00 degrees. DecLination is 0.00 degrees, Convergence is -1.17 degrees. Calculation uses the minim~ curvature method. Presented by Baker Hughes [NTEQ UNOCAL PROPOSAL LISTING Page 2 GRANITE POINT Platform, Z2-13Rd Your ref : 22-13 Rd~-5 Version #3 Granite Point Field,Cook Inlet, Alaska Last revised : 4-Apr-96 Con~nts in wellpath MD TVD Rectangular Coords. Co~nent 11400.00 9920.75 2027.35 S 5064.35 E KOP - Sidetrack Pt 11738.96 10079.16 2039.23 S 5362.38 E End Angle Build 12068.88 10189.32 2043.30 S 5673.30 E End of Turn 13943.26 10815.00 2012.47 S 7439.89 E TD Casing positions in string 'A' Top ND Top TVD Rectangular Coords. Bot I~ Bot TVO Rectangular Coords. Casing n/a 9920.75 2027.35S 5064.35E n/a 9920.75 2027.35S 5064.35E 9 5/8" Casing n/a 9920.75 2027.35S 5064.35E n/a 9920.75 2027.35S 5064.35E 7" Casing Targets associated with this wellpath Target name Position T.V.D. Local rectangular coords. Date revised 22-13 Rcl~3 (1)26-Mar 267695.000,2544797.000,0.000010168.00 2045.13S 5656.00E 21-Mar-96 22-13 Rd~r5 (2)26-Mar 269467.000,2544790.000,0.000010815.00 2015.92S 7427.83E 21-Mar-96 All data is in feet unless otherwise stated Coordinates from NW Corner of Sec. 13, TIO#, R12~/ SM and TVD from RKB (Rig #156) (115.00 Ft above mean sea level). Bottom hole distance is 6075.21 on azimuth 86.53 degrees from wellhead. Total Dogleg for we[[path is 20.25 degrees. Vertical section is from wellhead on azimuth 89.00 degrees. Declination is 0.00 degrees, Convergence is -1.17 degrees. Calculation uses the minim~ curvature method. Presented by Baker Hughes INTEQ UNOCAL GRANITE POINT Platform 22-13Rd slot ~3-2 Granite Point Field Cook Inlet, Alaska CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 22-13 RcbIF5 Version #3 Our ref : prop1579 License : Date printed : 4-Apr-96 Date created : 21-Mar-96 Last revised : 4-Apr-96 Field is centred on n60 59 36.731,w151 18 33.112 Structure is centred on n60 57 52.745,w151 20 20.0(>6 Slot location is n60 5~ 29.311,w151 19 52.203 Slot Grid coordinates are N 2544550.000, E 263409.000 Slot local coordinates are 2379.66 S 1375.79 E Reference North is True North Main calculation performed with 3-D Minin~znOistance method Object wellpath PM$S (11453 - 13821'>,,22-13Rd2,GRANITE POINT PMSS <6738 - 12036'>,,22-13Rd,GRANITE POINT Pl Closest approach with 3-D minin~zn distance method Last revised Distance M.D. Diverging from M.D. 20-Dec-95 0.2 11400.0 12160,0 20-Dec-95 0.0 11400.0 11625,0 UNOCAL GRANITE POINT Platform,22-13Rd Granite Point Field,Cook Inlet, Alaska CLEARANCE LISTING Page 1 Your ref : 22-13 Rcl~3 Version Last revised : 4-Apr-96 Reference wel[path Object we[lpath : PMSS <11453 - 13821'>,,22-13Rd2,GRANITE POINT Platform Horiz Min'm TCyt M.D. T.V.D. Rect Coorainates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 11400.0 9920.8 352.3N 3688.6E 11400.0 9920.9 352.5N 3688.5E 331.4 0.2 0.2 11500.0 99?6.6 349.2N 3771.4E 11499.9 9978.3 352.1N 3770.2E 337,4 3.5 3.5 11600.0 10025,0 345.8N 3858.8E 11599.6 10032.7 355.1N 3853.7E 331.0 13.1 13.2 11700.0 10065.5 342.0N 3950.1E 11700.5 10082.1 358.2N 3941.5E 332.0 24.7 24.9 11800.0 10099.5 338.2N 40~.1E 11801.1 10124.6 358.6N 4032.8E 331.0 34.2 34.4 11900.0 10132.9 336.1N 4138.3E 11903.6 10162.8 360.2N 4127.7E 336.4 39.9 39.9 12000.0 10166.3 335.6N 4232.6E 12006.4 10192.5 359.7N 4226.2E 345.1 36.1 36.2 12100.0 10199.7 336.9X 4326.8E 12106.7 10213.6 358.6N 4324.2E 353.0 26.0 26.1 12200.0 102.~3,1 338.5N 4421.1E 12203.8 10227.2 362.6N 4420.2E 357.9 24,8 24,9 12300.0 10266.5 340.2N 4515.3E 12300.3 10238.6 371.3N 4515.7E 0.6 41.8 42.6 12400.0 10299.8 341.8N ~609.6E 12398.2 10253.4 38~.6N 4611.6E 2.7 62.6 63.9 12500.0 10333.2 343.4N 4703.8E 12495.4 10276.5 404.1N 4703.7E 359.9 8~.1 85.2 12600.0 10366.6 345.1N 4798.1E 12591.5 10303.6 430.0N 4~92.2E 356.0 105.9 10~.1 12700.0 10400.0 346.7N 4892.3E 12685.5 10330.6 457.0N 4878.1E 352.6 131.0 136.0 12800.0 10433.4 348.4N 4986.6E 12780.3 10358.4 485.9N 4964.0E 350.7 158.2 164.8 12900.0 10466.8 350.0N 5080.8E 12876.2 10386.8 515.5N 5050.6E 349.6 186.2 194.2 13000.0 10500.1 351.7N 5175.1E 12971.0 10415.9 545.2N 5135.8E 348.5 214.7 224.3 13100.0 10533.5 353.3N 5269.3E 13066.5 10446.0 575.6N 5221.2E 347.8 243.7 254.7 13200.0 10566.9 355.0N 5363.6E 13163.4 10477.7 606.5N 5307.4E 347.4 272.7 284.8 13300.0 10600.3 356.6N 5457.8E 13259.1 10509.7 636.7N 5392.4E 346.8 301.5 315.2 13400.0 106~3.6 358.2N 5552.1E 13352.3 10540.9 6~>6.2N 5475.1E 346.0 330.7 347.4 13500.0 10667.0 359.9N 5646.3E 13442.5 10570.9 695.8N 5554.9E 344.8 361.2 379.3 13600.0 10700.4 361.5N 5740.6E 13543.0 10602.8 728.6N 5644.3E 345.3 391.8 410.9 13700.0 10733.8 363.2N 5834.8E 13636.8 106~1.9 758.5N 5728.4E 344.9 421.9 443.0 13800.0 10767.2 364.8N 5929.1E 137'50.5 10660.9 788.7N 5812.2E 344.6 452.4 13900.0 10800.6 366.5N 60Z3.3E 13821.0 10689.0 817.7N 5893.2E 343.9 482.6 All data is in feet unless otherwise stated Coordinates from slot ~r5-2 and TVO from RKB (Rig #156) (115.00 Ft above mean sea [eve[). Vertical section is from wellhead on azimuth 89.00 degrees. Dec£ination is 0.00 degrees, Convergence is -1.17 degrees. Calculation uses the minim~ curvature method. Presented by Baker flughes INTEQ UNOCAL GRANITE POINT Platform,22-13Rd Granite Point Field,Cook Inlet, Alaska CLEARANCE LISTING Page 2 Your ref : 22-13 Rcl~3 Version Last revised : 4-Apr-96 Reference wellpath Object welLpath : PMSS <6T58 - 12036'>,,2Z-13Rd,6RANITE POINT PLatform Horiz Min'm TCyL M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 11400.0 9020.8 352.3N 3688.6E 11400.0 9920.8 352.3N 3688.6E 270.0 0.0 0.0 11500.0 9976.6 349.2N 3771.4E 11499.9 9974.5 348.1N 3772.6E 135.0 2.6 2.6 11600.0 10025.0 345.8N 3858.8E 11599.8 10022.7 347.4N 3860.1E 37.2 3.1 3.1 11700.0 10065.5 342.0N 3950.1E 11699.3 10071.6 347.9N 3946.7E 329.9 9.1 9.2 11800.0 10099.5 338.2N 4044.1E 11798.0 10119.4 348.7N 4033.1E 313.7 24.9 25.3 11900.0 10132.9 336.1N 4138.3E 11897.6 10166.7 348.5N 4120.7E 305.3 40.1 40.4 12000.0 10166.3 335.6N 4232.6E 11996.8 10212.6 346.3N 421~.6E 293.9 53.3 53.? 12100.0 10199.7 336.9N 4326.8E 12036.0 10230.8 345.6N 4243.3E 275.9 89.5 12200.0 10233.1 338.5N 4421.1E 12036.0 102~0.8 345.6N 4243.3E 272.3 177.9 - 12300.0 10266.5 340.2N 4515.3E 12036.0 10230.8 345.6N 4243.3E 271.1 274.4 - 12400.0 10~.8 341.8N 4609.6E 12036.0 10230.8 345.6N 4243.3E 270.6 372.7 12500.0 10333.2 343.4N 4703.8E 12036.0 10230.8 345.6N 4243.3E 270.3 471.8 12600.0 10~.6 345.1N 4~98.1E 12036.0 10230.8 345.6N 4243.3E 270.0 571.1 12700.0 10400.0 346.7N 4892.3E 12036.0 10230.8 345.6N 4243.3E 269.9 670.7 12800.0 10433.4 348.4N 4986.6E 12036.0 10230.8 345.6N 4243.3E 269.8 770.4 12900.0 10466.8 350.0N 5080.8E 12036.0 10230.8 345.6N 4243.3E 269.7 870.1 13000.0 10500.1 351.7N 51~5.1E 12036.0 10230.8 345.6N 4243.3E 269.6 969.9 13100.0 10533.5 353.3N 5269.3E 120~6.0 10230.8 345.6N 4243.3E 269.6 1069.7 13200.0 10566.9 355.0N 5363.6E 12036.0 10230.8 345.6N 4243.3E 269.5 1169.6 13300.0 10600.3 356.6N 5457.8E 12036.0 10230.8 345.6N 4243.3E 269.5 1269.5 13400.0 106~3.6 358.2N 5552.1E 12036.0 10230.8 345.6N 4243.3E 269.4 1369.4 13500.0 10667.0 359.9N 56~6.3E 120~6.0 10230.8 345.6N 4243.3E 269.4 1469.3 13600.0 10700.4 361.5N 5740.6E 12036.0 10230.8 345.6N 4243.3E 269.4 1569.2 13700.0 107'53.8 36~.2N 5834.8E 12036.0 10Z~0.8 345.6N 4243.3E 269.4 1669.2 13800.0 10767.2 364.8N 5929.1E 12036.0 10230.8 345.6N 4243.3E 269.3 1769.1 13900.0 10800.6 366.5N 6023.3E 12036.0 10230.8 345.6N 4243.3E 269.3 1869.1 At[ data is in feet un[ess otherwise stated Coordinates from slot f~-2 and ~ from RKB (Rig #156) (115.00 Ft above mean sea [eve[). Vertical section is from wellhead on azimuth 89.00 degrees, Declination is O.IXI degrees, Convergence is -1.17 degrees. Ca[culationuses the minim~ curvature method. Pres~ted by Baker Hughes INTEQ Casing Design Summary Well: GP 22-13 Field: Casing Mud WT Size (PPG) Granite Point Date: 4/5/96 M.S.P. (psi) Design by: Mitchell Damm Max. Kick Tolerance (BBLS) 7" 8.4 1,480 4-1/2" 8.4 NA 1,773 NA *** Slotted Liner*** Casing Bottom Top Length Wt Grade Thread Size (FEET) (FEET) (FEET) (LB/FT) Connection 4-1/2" 13,934 12,753 1,181 12.6 L-80 SC-Buttress TVD 10,965 10,015 Casing Weight Tension Minimum * Collapse * Collapse Collapse Size W/O BF Top of Strength TDF Pressure #1 Pressure n2 Resist. Section Tension ~ Bottom ~ Bottom Tesnsion (LBS) (LBS) (1,000/LBS) (psi) (psi) (psi) 4-1/2" 14,881 14,881 289 19.4 NA NA NA * * Burst CDF#1 CDFtt2 Pressure (psi) NA NA NA * Collapse pressures are calculated using two methods (checks). 1) Difference between two cement slurries (i.e. AVG of a 15.8 PPG (tail) & 14.2 PPG (lead) = 15 PPG. Subtract a mud of 9.5 PPG = 5.5 PPG = .286 psifFT gradient X TVD of the easing string.) 2) Difference between Mud Weight on the outside and gas lift gas (0.0 psi/FT) on the inside. (i.e. Multiply (.052 X MW - 0.0 psi/FT) X the TVD of the Top of Cement. Burst pressure is calculated. (BLIP ~ the depth of the next casing X TVD next casing) X (0.5 = half of weHbore evacuated. Minimum Yield BDF Strength (psi) NA NA KT2213R2,XLS 4/4/96 FIT,T:- UP ~ ~ i 3FLOW BOP 13%'3000 pm PIPE RAM~ 3%' 5000 psi B~ RAMS 13%'5000 pm SPOOL , t'Q'T.T.~ ~3e,,gS000 p~ .~><~>~ CHOKE LINE 4- 5000 psi I I, 4" 5000 psi PIPE RAMS 13%'5000 pm 1 T.TNE--~ RISER 5000 psi COOK INLET PLATFORMS:' BOPE STACK 1378T. 5:0:0.0~ psi A., ~' - 1§o LB ON RIG HEADER SECTION FRONT VIEW 4"- 5000~ BUFFER TANK FRONT VIEW GAUGE & REWOTE PANEL ';'~ TRANSMITTER ~ ~_, '~ GA~E FLANGE BEHI~ ~ADER I ! par Drawing 2 3 ~ Flange, 4, 1/16" - ~000# 3 ! A(~DCmN, 4 1116" - 5000# Flg X ~" NP~ Lg. Flg. 3A I A~Cer. 4 1/16" - 5000# ¥1V. X 4" NPS ~m. SWiVel A Ad~Cex. 4 1/16* - 5000# ~1~. X 3" NP$ NXDpAe 90 5 2 )~Ml~Ce.c. 3 1/16' - lClO00# Pig, X 3" NPS 2 A~a~r, 3 1/16* '- I0000# Flg. X 3' HPS NtDDZe 7 I 1/16" - 5000It NPN Nil~le 8 I TI'B~J:I~CBr F~. 2 1/16w 5000# w/ 2 - 2" LPT 10 2 SWaCO ~ 2 9/1E" - 10,000# rsmol~ opara-,.ad c~u~r, a w$.lr.13panel 11 3 5 - way NPS f_t~w bloc~, 4X4X3X3X2 ll 3 13 3 15 2 17 1 19 Maximum Surface Pressure Calculations Well: 22-13RD#2 Casing Size: 7" Depth Interval: 0'-14,357' Hole Size: 6.00 General Information: Anticipated Mud Weight (MW): Shoe Depth (D,~,,~): Estimated Fracture Gradient (at the Shoe): Total Depth (Dm): Bottom Hole Pressure Gradient (BHPG): Gas Gradient (GG); (assumes worse case): Maximum Gas Column Height in wellbore: 8.4 PPG 11,377 MD 3,943 MD 0.437 psi/FT 99O6 TVD 0.85 psi/FT 10817 TVD 0.20 psi/iT 0.10 psi/FY 12,000 Feet (@ anticipated Mud Weight) Maximum Surface Pressure Calculations: The wellbore volume is determined using the height of gas column in wellbore when top of gas bubble is at the shoe- during a gas kick situation. A percentage of the gas column heist (Fit), found in the Maximum Kick Tolerance Calculations, is used. Maximum Surface Pressure = Maximum Bottom Hole Pressure - Hydrostatic Pressure (Gas Volume +Mud Volume) MSP = Pm~m. GG*Ht - .052*MW*(Dm-Ht) MSP = 1,480 psi Hydrostatic Pressure at the Shoe Calculations: The greatest hydrostatic pressure at the shoe (Pshoe) is when the gas bubble reaches the shoe. Assuming a constant bottom hole pressure is applied while circulating out the gas kick. A conservative estimate would be the maximum surface pressure plus the hydrostatic pressure at the Shoe Depth (Dshoe). P~ = MSP + .052*MW*D~ Pshoe= 5,807 psi FP~oe= 8420 psi The pressure at the shoe (Pshoe) is less than the fracture pressure at the same shoe. Therefore the shoe integrity is sufificient to adequately handle a gas kick. Pressure Differential Across the Shoe: Pressure differential across the casing shoe = Pshoe - Maximum pore pressure at shoe DPshoe = Pshoe - Pmax ~ shoe = Pshoe - BHPG * D~ DP shoe = 3,826 psi The DPshoe is less that the internal yield of the casing. KT2213R2.XLS 7" MSP 4/9/96 Maximum Kick Tolermlce Calculations Well: GP 22-13 RD#2 Casing Shoe: 7" General Information Variables 1 7" Casing Shoe (from RT) 9,906 Feet (TVD) Dsho~ 2 Fracture pressure Gradient 0.85 psi/FT FPG 3 Fracture pressure at the 7" Shoe 8,420 psi FP~ho~ 4 Proposed TI) of the 4-1/2" Casing Shoe (TVD) 10,817 Feet (TVD) Dm 5 C-5 Pore pressure gradient 0.20 psi/FT PpG 6 Maximum anticipated pore pressure ~ TD 2,163 psi Pm~xt~ 7 Mud Weight See table PPG MW 8 Gas Gradient 0.10 psi/FT GG 9 ,Average open hole size 6.00 Inches ODoa 10 Drillpipe OD 3.50 Inches OD~P 11 iCapaeity of open hole by drillpipe O.0231 BBL/FT CAP 12 Height of gas column in wellbore when top of gas is at the shoe HT Feet (TVD) Ht Assumptions for Granite Point Field: Fracture Pressure Gradient = .9 PSI/FT; and Maximum Pore Pressure Gradient = .52 PSI/FT. (GP 13-13; 1967) All calculations assume that water based mud is used and does not take into account gas solubility in oil based mud. Gas bubble height in weilbore (Ht) calculation with gas bubble top at 7" shoe. FPshoe + Pgas bubble + Proud = Pmax~ TD FPsho~ + GG*Ht + .052*MW*(Dx~-Dsho~-Ht) = Pmax~m Gas Volume (GV) calculation at 7" shoe. GV = CAP*Ht Kick Tolerance calculation: Gas volume in wellbore at TD. P1V1 = P2V2. Assume constant temperature. Kick Tolerance * P~ m = GV * FP Mud Weight Gas Bubble Height Gas Volume ~ Shoe Kick Tolerance (PPG) (Feet) (BBLS) (BBLS) 7.0 24,956 575 2,240 7.2 24,044 554 2,158 7.4 23,200 535 2,082 7.6 22,414 517 2,012 7.8 21,683 500 1,946 8.0 20,999 484 1,885 8.2 20,359 469 1,827 8.4 19,758 456 1,773 8.6 19,194 443 1,723 8.8 18,662 430 1,675 9.0 18,160 419 1,630 9.2 17,686 408 1,587 9.4 17,238 397 1,547 9.6 16,812 388 1,509 9.8 16,409 378 1,473 10.0 16,025 370 1,438 10.2 15,660 361 1,405 10.4 15,312 353 1,374 10.6 14,980 345 1,344 10.8 14,663 338 1,316 11.0 14,360 331 1,289 KT2213R2.XLS 4/4/96 1,000 2,000 4,000 5,000 6,000 7,000 8,0OO lO,OOo Granite Point Field Fracture Gradient Data 0 0.2 0.4 0.6 0.8 1 1.2 L4 Fr~mr~ Gradient (PSI/F~ 1.6 FRACI}ATA. XI.~ 1/4D6 Fracture Pressure Data Granite Point Field Platform Well Date Casing Frac Csg Shoe EMNV Notes Size Gradient Depth PPG Psi/ft. TVD I I GPP ' ll-13rd [ L'14/92 9-5/8" 0.96 9.966 18.41 GPP 51], 8/7/92 13-3/8' i 3.80~ 19.21 51'1-;28/92 18-5/8' 0.83 1.OiO GPP 16.81 GPP 51 !g/25/92 9-5/8' 1.05 9,592 20.21 GPP 50 5/27/92 18-5/8' 0.91 982 17.5 GPP 50 6/4/92 13-3/8' 0.84 4.208 16.2: GPP 50 6/27/92 9-5/8" 0.93 9,877 17.9 ~ , Anna llrd I !0/23/94 13-3/8' 0.891 2.976 17.2 Anna llrd] i1/11/94 9-5/8" 0.921 8.750 17.7 * 3rd i !~10/94 9-5/8" 0.751 7,839 14.5 ..Xama { 50 I :'8/95 18-5/8" 1.381 1.160 26.6 i , , Anna 50 i U13/95 13-3/8" 1.01 4.25! 19.5 , Anna 50 I ,3/8/95 9-5/8" 0.861 9,844 , 16.5 Anna 51 1129195 18-5/8" 1.361 1.130 26.2 Anna 51 5/15/95 13-3/8" 0.711 3,796 13.6 Anna 51 613195 9-5/8" 0.881 9,842 17 * ! Anna 52 2Y3/95 18-5/8" 1.411 1,153 27 Anna 52 3/27/95 13-3/8" 0.841 3,940 16.15 Anna 52 4/15/95 9-5/8" 0.91 9,470 17.6 * Anna 7rd2 8/25/95 9-5/8" 0.961 4,439 18.5 · Anna 7rd2 ' 9/6/95 7" 0.82 9,589 15.8 ! i Not~: All ~ gra~ents repon~ have been cotreaed for air and water gaps. * lndicams a WIT)-Fomon lntegnty Test was achieved, not actual leak off. ~CDAT,~XI~ 1/4~ Unocal Corporation Oil & Gas Operations 909 West 9th Avenue, P. ©. Box 196247 Anchorage, Alaska 99519-6247 UNOCAL Kevin A. Tabler Land Manager Alaska Business Unit April 4, 1996 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3 001 Porcupine Drive Anchorage, AK 99501-3192 GRANITE POINT FIELD PERMIT TO DRILL 22-13RD #2 ADL 18761 Dear Chairman Johnson: Enclosed, in triplicate, is Union Oil Company of California's (Unocal) application for Permit to Drill Granite Point Field, well number 22-13RD #2 (form 10-401) pursuant to 20 AAC 25.005 and our check No. 2000044 in the amount of $100.00 as required under 20 AAC 2S.00S (o) (~). If you require additional information, please contact Mitch Damm at 263-7679 or Roxanne Sinz at 263-7623. We appreciate your review and trust the enclosed is satisfactory. V, ery truly yours, / Kevin A. Tabler Enclosures h?P 0 9 ' 99B GaS ConS. commission Anchora9e WELL PERMIT CHECKLIST INIT CLASS WELL NAME J~-~!~_~, K~--/~/~ROGRAM: exp O dev ri redrl aery O wellbore seg D ADMINISTRATION 1. Permit fee attached .................. N ,,%.~,~3~3/.~ J ~/. 2. Lease number appropriate ............... N . z~ . 3. Unique well name and number .............. N 4. Well located in a defined pool ............. N 5. Well located proper distance from drlg unit boundary.. N 6. Well located proper distance from other wells ..... N 7. Sufficient acreage available in drilling unit ..... N 8. If deviated, is wellbore plat included ........ N 9. Operator only affected party .............. N 10. Operator has appropriate bond in force ......... N 11. Permit can be issued without conservation order .... N 12. Permit can be issued without administrative approval.. N 13. Can permit be approved before 15-day wait ....... N REMARKS ENGINEERING APPR DA~E 14. Conductor string provided ................ 15. Surface casing protects all known USDWs ......... 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will coverall knoWnforPrOductive horizonsB & permafrost ....... 19. Casing designs adequate C, T, .... 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved· 22 Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate ........... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ..................... 26. BOPE press rating adequate; test to ,~~ psig.~ 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ............ GEOLOGY / 30. Permit can be issued w/o hydrogen sulfide measures .... Y · Data presented on potential overpressure zones ..... Y ~ .-~ 32. Seismic analysis of shallow gas zones .......... 33. Seabed condition survey (if off-shore) ....... 34. Contact name/phone for weekly progress reports . · .~ · Y N [~plorato~ only] / GEOLOGY: ENGINEERING: BEW COMMISSION: DWJ JDN ~ Comments/Instructions: Z O HOWIIjb - Ag, FORMS\cheklist rev 11195
