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Home My WebLink About177-075STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMh,._.iION RECEIVED WELL COMPLETION OR RECOMPLETION REPORT AND L06u_`"'J 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned El , Suspended[] 20AAC 25.105 20AAC 25.110 GINJ ❑ WI NJ ❑ WAG ❑ WDSPL ❑ No. of Completions: 1b. Well Class: A Development 2] xploratory LJ Service ❑ Stratigraphic Test ❑ 2. Operator Name: Hilcorp Alaska, LLC 5. Date Comp., Susp., or Aband.: 11/8/2013 12. Permit to Drill Number: 177-075 . , ' 3. Address: 3800 Centerpoint Drive, Suite 100, Anchorage, AK 99503 6. Date Spudded: N/A 13. API Number: 50-733-20311-00-00 4a. Location of Well (Governmental Section): Surface: 794' FNL, 603' FEL, Sec 12, T10N, R12W, SM, AK Top of Productive Horizon: 1630' FSL, 1816' FEL, Sec 12, T10N, R12W, SM, AK Total Depth: 482' FSL, 1109' FWL, Sec 12, T10N, R12W, SM, AK 7. Date TD Reached: N/A 14. Well Name and Number: Granite Pt St 18742-17 8. KB (ft above MSL): 121' ft GL (ft above MSL): N/A 15. Field/Pool(s): Granite Point Field Hew►losk-ee 9. Plug Back Depth(MD+TVD): 3,198' 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 266847.63 y- 2551348.01 Zone- 4 TPI: x- y- Zone- Total Depth: x- y- Zone- 10. Total Depth (MD + TVD): N/A 16. Property Designation ADL018742 , 11. SSSV Depth (MD + TVD): N/A 17. Land Use Permit: N/A 18. Directional Survey: Yes ❑ No E]- (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: (ft MSL) 20. Thickness of Permafrost MD/TVD: N/A 21. Logs Obtained (List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MD/TVD: N/A 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 20" 91.5# X-52 Surf 610' Surf 607' 13-3/8" 54.5#, 61#, 68#,72# K-55 & L-80 Surf 3514' Surf 2,888' 9-5/8" 40#, 43.5#, 47# S-95 3,634' 10,663' 2,975' 8,700' 24. Open to production or injection? Yes ❑ No If Yes, list each interval open (MD+TVD of Top and Bottom, Perforation Size and Number): N/A �C.ANNEQ 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑ DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24 -Hour Rate __Oo. Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No ❑ Sidewall Cores Acquired? Yes ❑ No ❑ If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. N/A RBINS MAR 21 2n° Form 10-407 Revised 10/2012 CONTINUED ON REVERSE Submit original only '7*_-- G lc) . / -� /e'110l� 'IM X11 // 1 -/G 4 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 0 No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top N/A N/A needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base N/A N/A Formation at total depth: 31. List of Attachments: 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Luke Keller Email: Ikeller hllcor .gom Printed Name: Luke Keller- Title: Drilling Engineer Signature: Phone: 907 777-8395 Date: 12/9/2013 FAr INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1b: Classification of Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well 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. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. 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. Form 10-407 Revised 10/2012 Hilcorp Alaska, LLC 30" 20" ,' ` 4 13-3/8 It 3 TOC 9330 4 5 dcj-- R ss( -C, TD: 10,674' MD / 9,972' TVD SCHEMATIC Casine Detail Anna Platform WELL #: Anna 17 11/08/2013 SIZE WT GRADE CONN ID TOP BTM. 30 3,614' X-55 - Surf - 20 91.5# X-52 19.124 Surf 610' 13-3/8 54.5, 61, 68, 72# K-55 & L-80 BTC 12.347 Surf 3,514' 9-5/8" 40, 43.5, 47 # S-95 BTC 8.681 3,634' 10,663' Item Detail NO Depth Item 1 3,198' Top of kick off plug 2 3,614' 9-5/8" Casing Stub 3 3,684' CIBP 4 9,395' Top of P&A cmt 5 9,551' Cement Retainer 6 9,660' Top pert 7 10,334 Bottom pert REVISED: 12/09/2013 REVISED BY: JLL Lc_ PTT) Hilcorp Alaska, LLC s 3-/-r3 Weekly Operations Summary Well Name JAPI Number lWell Permit Number IStart Date EndDate AN -17, 50-733-20311-01-00 213-049 1 10/8/2013 Daily Operations: 10/08/13 -Tuesday Cleaning pits, R/U shock hoses from pits to rig. Remove tree cap from AN -17. R/U 3-1/2" tubing riser to rig floor. R/U circ lines and manifold to circ well. Install cooling pump splash guard on dwk brk cooling tank. Finish cleaning all pits, trip tank and cmt water tank. Test pop offs on pumps #1 & #2. Pressure test circ lines to master valve and annulus valve. 250-3000 psi (ok). PJSM / Pump down the annulus; Tbg = zero psi, Tbg X 9-5/8" = zero psi, 9-5/8" x 13-3/8" = 285 psi, 13-3/8" X 20" = 175 psi. 10/09/13 - Wednesday Continue pump do annulus @ 2 bpm @ no psi. Established returns t/ choke & gas buster @ 15 bbis away shut dn, shut in, to swap lines. Work on RBS stab & grab function. Pump drill water do tbg taking returns 9-5/8" annulus t/ choke & gas buster @ 2 bpm @ 100 psi, 3 bpm @ 218 psi & pump 100 bbls w/ no losses & do pump & monitor well dead & stable. R/up slick line & test lubricator 250-3000 (ok). Run #1 w/ 2.80" GR tag @ 52' work tools t/ 62' POOH. Run #2 w/ 2.25" GR tag @ 1,582' work tools t/ 1,584'. Run #3 w/ 2.75" star bit Tag @ 1,586' work tools t/ 1,588'. Run #4 w/ hole finder (3/4" poney tail, w/ 24 tails ) while pumping do tbg @ 4 bpm @ 350 psi locate hole both ways @ 1,260' rkb). Continue RIH & tag 1,588'. Run #5- #18 ran bailers f/ 1,588't/ 1,638'. Recovering sand like paraffin in bailer. Made it to 1,638' with the 1.75". Made it to 1,629' with a 2.25" bailer. Alternating between bailers to make hole. Made 50' in 13 hrs of bailing. 10/10/13 -Thursday Run #19 & #20 work 2.25" bailer f/ 1,635't/ 1,637' bailer w/ very little recovery. R/dn slick line. Notified AOGCC of upcoming coil BOP test / Witness of test was waved by Jim Regg @ 09:29 on 10-10-13. R/dn circ lines to tbg / L/D 16" flow nipple / L/dn tbg landing jt & tree cap x flange. Re -install 16" flow nipple for coil tbg use. Run line from pits to feed the coil unit. Set landing on the drilling conex to take measurements and remove. Remove old dump lines in pit 3 & 4 and cap off. Work on suction valves. Unload coil unit and equipment from the boat and spot in place. Spot coil BOP'S & riser in the cellar. N/U BOP's and riser on the well head. Set injector head on the rig floor. Tbg = zero psi, Tbg X 9-5/8" = zero psi, 9-5/8" x 13-3/8" = 290 psi, 13-3/8" X 20" = 165 psi. 10/11/13 - Friday Pull out and string hydraulic lines to coil injector & BOP's. Bring riser and lubricator to the rig floor. R/U return lines and bypass from BOP's. Working on rebuilding pit suction valves. Clean and organize rig floor and cellar. R/U lines to injector, BOP's, pump unit. Function test all equipment and bops. Stab coil in injector. Fill BOP'S with water. Preform accumulator test. Test BOP's & choke valves to 250 psi low/ 3000 psi high. M/U lubricator & riser. Stab injector. Test stripper & check valves in coil. 10/12/13 -Saturday Finish testing 1-3/4" Coil tbg BOPE's. M/up & test CT bha #1= 2.70" bladed bit + XO + 1-1/8" M1 -V Mtr + 2.13 circ sub + 2.13" Hyd Disconnect + 2.13" dual chk valve +2.25" slip connector. Brk circ to pit & fill choke gas buster & possum belly & zero PVT & set both counters & open well. RIH @ 3/4 bpm @ 520 psi & weight chk @ 1000 & 1500' Up rate t/ 1.5 bpm @ 940 psi & engage scale/fill @ 1,633'& drill scale/fill t/ tbg tail @ +/- 9,630'. Keeping mtr loaded & getting 25-35 fpm & wt. Chk every +/-250'& wiper trips +/- 500' Exit tail +/- 70' T/ 9,700' w/ no losses. POOH F/ 9,700' with coil while pumping @ 1.5 bpm @ 1250 PSI. Blow down surface lines and choke. L/D BHA #1 and R/D injector, Riser, surface lines, BOPS. R/U & start blow down the coil with 12 nitrogen bottles. 13,200' coil. Tbg = zero psi, Tbg X 9-5/8" = zero psi, 9-5/8" x 13-3/8" = 280 psi, 13-3/8" X 20" = 170 psi. Hilcorp Alaska, LLC I�Jor,i ,lu.6u. I I t Weekly Operations Summary Well Name —::API Number Well Permit Number IStart Date lEnd Date AN -17A 50-733-20311-01-00 213-049 1 10/8/2013 Daily Operations: 10/13/13 -Sunday Contipue R/dn CTU. Re -install 3_1/2" tbg_riser for wire line. Pumping & tree removal work. Vacuum out and Clean flow box. Drain pits of drill water to production. Finish removal of old stack robber blower assy. Perform modifications t/ new stack robber blower assy. Vacuum cutting out of pits. R/up E -line RIH w/ 1-9/16" X 6' tbg punch gun, loaded w/ 22 shots de -centralized @ 1/4" holes. RIH w/e-line and start to Tie in t/ seal assy. Finish Tie in t/ seal assy & place gun on depth. Attempt fire (no indication of fire). POOH to chk tools. Replace, test tool. RIH check with 1-9/16" X 6' tbg punch gun, loaded w/ 22 shots. Locate collar on first full jt above the packer. Set top shot @ 9,576'. Btm shot @ 9,582'. Fire hole punch with good indication of voltage. POOH. R/D wire line. R/U to circ down the tubing and take returns up the annulus through the gas buster. Test lines T/ 3000 psi. Break circ & stage up pumps T/ 10 bpm @ 1300 psi. Circ 250 bbls started to get small amount of dirty fluid. Circ 835 bbl total with spotty dirty fluids mixed in. Fluid started to clean up @ 800 bbl. Shut down pumps & monitor well. Well static. Blow down surface lines. Remove landing joint. R/D surface circ lines & set TWC. TWC set @ 0200. N/D tree. Remove tree & verify lock downs are turning. Inspect hanger threads. 10 turns by hand. Threads not pitted looked good after cleaning 1/4 in of scale/buildup. Tbg = zero psi, Tbg X 9-5/8" = zero psi, 9-5/8" x 13-3/8" = 275 psi, 13-3/8" X 20" = 175 psi. 10/14/13 - Monday Remove (2) seized well head bolts w/ sawzall. Clean ring groove, stab riser & soft bolt. Work on chg/out of stack robber blower assy. Set BOPE riser from stump & soft bolt start torqueing Bolts from btm up. Hook up Koomey lines, install turn buckles, function test. Chg btm rams t/ 9-5/8" install 16" flow nipple. Install saver sub & stabbing guide on topdrive. Install new heat recovery unit on turbine. M/U testing equipment and install 3-1/2" test joint. Test BOP's, 250 psi low/ 3000 psi high as per AOGCC regulation. Mr. Jim Regg w/ AOGCC waived witness of initial Bope test @ 12:02 pm 10-14-13. Tbg = zero psi, Tbg X 9-5/8" = zero psi, 9-5/8" x 13- 3/8" = 275 psi, 13-3/8" X 20" = 175 psi. 10/15/13 -Tuesday Finish testing w/ 3-1/2" test jt. Build 9-5/8" test jt & test btm 9-5/8" ram 250 psi low / 3000 psi high / Failed. Pull test jt Chk conn & Teflon threads & re test. Pull test jt & BPV & install TWC & re -test, Failed. Break down 9 5/8 test jt. M/U 5-1/2" test joint. Test Annular and top VBRs on 5-1/2". 250 psi low/3000 psi high. Break down test joint. M/U to TD & test blinds & TD. Perform accumulator test. Blow down all surface equipment. Pull TWC. Work on drawworks crown saver & brake splash guard. Tbg = zero psi, Tbg X 9-5/8" = zero psi, 9-5/8" x 13-3/8" = 275 psi, 13-3/8" X 20" = 175 psi. Hilcorp Alaska, LLC kla-ka.LIA Weekly Operations Summary Well Name JAPI Number JWell Permit Number JStartDate End Date AN -17A 50-733-20311-01-00 213-049 1 10/8/2013 Daily Operations: 10/16/13 - Wednesday Inspect draw works crown saver. M/U landing joint. BOLD, Pull hanger off seat & 125k. Work string up to 145k trying to free. No luck. R/U wire line. RIH & make cut with a 2" radial cutter. @ 9,586'+/- WLM. POOH, R/D wire line. Pull hanger working wt up to 175K. Came free. L/D hanger & landing it. String wt 77k + 55K TD. POOH L/D 3-1/2 tubing F/ 9,586'T/ 8,333'+/-. Found hole in joint #37 1253' RKB. Pull 10 more joints to inspect to 8100'+/-, no holes. Spotty scaleup to 1/2 in thick. Circ btm up. No gas. POOH L/D 3-1/2 tubing F/ 8,100'T/ 5,600'+/-. Hole taking the correct fill. Tbg =zero psi. Tbg X 9-5/8" =zero psi. 9-5/8"x 13-3/8" =290 psi. 13- 3/8" X 20" = 165psi. 10/17/13 - Thursday POOH. Finish laying down 3-1/2" tubing D casing equipment. Clean rig floor. M/U landing it. and set 8-15/16's 1.13 wear bushing. M/U BHA #1, 8.5 bit, casing scraper, bit sub W/ float, oil jars, x.o., 6 D.C.'s, x.o.,x.o., total length= 206.68'. P/U 5-1/2" D.P. Tallying and rabbiting as RIH to depth of 600'. Tbg = zero psi. Tbg X 9-5/8" = zero psi. 9-5/8" x 13-3/8" = 325 psi. 13-3/8" X 20" = 170 psi. 10/18/13 - Friday Continue picking up 5.5" D.P., filling pipe every 1500', tallying and drifting as RIH. Off load cement and pump into silos, fill ISO tanks with Baraklean flush fluid. Continue picking up 5.5" D.P to depth of 7,300', filling pipe every 1500', tallying and rabbiting W/ RIH. Tbg = zero psi. Tbg X 9-5/8" = zero psi. 9-5/8" x 13-3/8" = 50 psi. 13-3/8" X 20" = 170 psi. 10/19/13 - Saturday Continue RIH with BHA #1 picking up HT -55 drill pipe from 7,300' to 9,000'. Fill pipe every 1500'. Wash and ream 9,000' to 9,595', 8 BPM/320 psi. Tag TOF @ 9,595' with 10K down. P/U 290K, S/O 245K, Rt 245K @ 15K ft/lbs.**RKB difference of 19'. CBU @ 8 BPM/350 psi. No gas show. Close annular preventer. Attempt to establish injection rate by walking pressure up to 3100 psi @ .5 BPM. 13-3/8" x 9-5/8" annulus increased from 110 psi to 155 psi. Bled down from 3100 psi to 2820 psi/5 minutes. Bleed all pressures to 0 psi. Monitor well 15 minutes. Static. POOH with BHA #1 standing back D.P. in derrick. Stand back D.C.'s in derrick. Tbg = zero psi. Tbg X 9-5/8" = zero psi. 9-5/8" x 13-3/8" = 125 psi. 13-3/8" X 20" = 170 psi. 10/20/13 -Sunday Finish laying down BHA #1. Rig up a -line. Make up cement retainer. RIH with retainer. Correlate retainer on depth @ 9,551' WLM. Set retainer 9,551'- 9,553' WLM. *9,570' DPM. Rig down a -line. R/U cement standpipe to rig floor. Make up mechanical setting tool assm. (stinger). RIH with same, tag up at 9,565'. Space out w/ 15' pup. C/O bales, install head pin. R/U high pressure lines. Tbg = zero psi. Tbg X 9-5/8" = zero psi. 9-5/8" x 13-3/8" = 140 psi. 13-3/8" X 20" = 170 psi. 10/21/13 - Monday Pressure test cement lines 1000 L/5500 H. Establish injection rates: 1.2 BPM/3900 psi, 2.1 BPM/4600 psi. Pumped total of 77 bbls. Finish mixing mud push while doing calculations. Pump 15 bbls mud push lead. Cementers contaminated cement silo with mix water. Abort cement squeeze. Bleed off back pressure. Unsting from retainer and lay down space out joint. Change bales. POOH from 9,500' to 8,600'. Slip and cut 120' of drill line. POOH from 8,600' to surface. L/D Stinger assembly. R/U and pull wear ring. R/U 9-5/8" test joint. Set test plug. Remove old 9-5/8" rams. Install new 9-5/8" rams.; Start filling stack in prep for testing. Tbg = zero psi. Tbg X 9-5/8" = zero psi. 9-5/8" x 13-3/8" = 140 psi. 13-3/8" X 20" = 170 psi. Hilcorp Alaska, LLC Ilily. pAlu-ka At Weekly Operations Summary Well Name API Number 150-733-20311-01-00 Well Permit Number IStart Date lEnd Date AN -17A 213-049 1 10/8/2013 Daily Operations: 10/22/13 -Tuesday Test all BOPE 25013DOQP_$J fgrS Minutes. AOGCC waived witness at 16:30 hrs on 10-18-13 by Jim Regg, sent AOGCC copies of charts as per their request. R/D test joint, set wear ring. M/U cement stinger assembly RIH to 9,556'. C/O to long bales, R/U pup jt, X.O. and cement high pressure lines in prep for cement squeeze. Test lines 500/ 5500 PSI Stung in, put 1000 PSI on back side, perform injectivity test@ 2 BPM= 4100 PSI for a total of 24 bbls, bled pressures off, unstung, pumped 15 bbls lead mud push@ 13 ppg while holding 500 psi on backside. Attempted to batch up cement. Had to Abort cement job due to contaminated (chunky) cement in silo. Tbg = zero psi. Tbg X 9-5/8" = zero psi. 9-5/8" x 13-3/8" = 155 psi. 13-3/8" X 20" = 170 psi. Hilcorp Alaska, LLC t�,h,.�p:,lx•ka.�.Ll Weekly Operations Summary Well Name JAPI Number lWell Permit Number Start Date End Date AN-17A 50-733-20311-01-00 213-049 1 10/8/2013 Daily Operations: 10/23/13 - Wednesday Offload contaminated cement from silos and put into super sacks and load on boat. Load big cement silos on boat. Off load new cement silos spot on deck. R/U new silos to cement unit. Performed derrick inspection. Built 500 bbls of 9.4 mud. R/U temporary overboard line, 90% complete on Installation of centrifuge. General housekeeping around rig. Re-dress spare swivel packing for top drive. Offload cement and R/U to perform cement squeeze job. Hold P1SM for cement job. While holding 1000 psi back pressure, pump 15 bbl mud push• 60 bbl 15J8Og cement and 5 bbl mud push. Chase with 135 bbls drill mud. Sting into cement retainer_ Squeeze 50 bbls cement 3650 psi to 5200 psi end pressure. Unsting and spot 10 bbls cement on top of retainer. Cement in place @ 0400 hrs. R/D floor cement lines. POOH slowly 7 stands to 8,875'. Install 6" wiper ball. Circulate bottoms up at 8 BPM/220 psi. Tbg = zero psi, Tbg X 9-5/8" = zero psi, 9-5/8" x 13-3/8" = 155 psi, 13-3/8" X 20" = 170psi. 10/24/13 - Thursday Pumped 6" ball to clear pipe, circulate well clean@ 8 BPM@ 240 PSI. Pumped 800 BBLS (u-tubing), pumped another 400 BBLS (still u tubing), pumped another 400 BBLS. POOH fr: 8,875'- surface. L/D cement stinger assembly.; Clean rig floor. R/U handling equipment. M/U 3-1/2" stinger=26.85, tubing=835.77, X.O.=.98,X.0.=1.40,X.0.=3.67 BHA total=868.67'. RIH to 9,163'. Service crown, blocks, top drive, draw works and tong sheaves. RIH and tag good cement at 9,395'. Set 10k down weight on plug, POOH to 9,320'. Fluid pack choke and rig up chart recorder. Test cement plug to 500 PSI/ 30 min( charted ) Tbg = zero psi, Tbg X 9-5/8" = zero psi, 9- 5/8" x 13-3/8" = 180 psi, 13-3/8" X 20" = 170psi. 10/25/13 - Friday POOH fr: 9,320'- 7,000'. Engineers took measurements and looked at where we're going to mount the new ST-80 iron roughneck. POOH fr: 7,000'- stinger assembly. R/U handling equipment, L/D 3-1/2" tubing. Test casing/cement plug 1500 psi( charted ). R/U wire line. RIH and set CIBP at depth of 3,664'. Hooked up hoses on annulus to choke (tested) and bled off the 180 psi. Test CIBP to 1500 psi/ 30 minutes (charted ). R/U lubricator and wireline, RIM and unch holes at 31614'-3616' in the 9-5/8".casing = 9 holes at 3/8" each. Pump 9.5 ppg KWF down the well and back up the 13-3/8" annulus, pumped at 5bpm@ max psi= 480- stabilized at 250psi. Total bbls pumped= 515. Monitor well (static). R/D annulus hose to choke, clear rig floor. RIH w/ 1500' D.P. Tbg = zero psi, Tbg X 9-5/8" = zero psi, 9-5/8" x 13-3/8" = 0 psi, 13-3/8" X 20" = 180psi. 10/26/13 - Saturday RIH with 15 stands drill pipe. P/U RTTS. Set at 160'. Test above RTTS at 3000 psi. Good test. Pull wear bushing. Clean out flow box. Check 13-3/8" x 9-5/8" annulus and insure to be static. Break down choke and kill lines. Isolate accumulator. N ROPE. Rerr,9ye__._ grating around _we1LI1sJ_N/D tubing spool and valves. Prep and weld emereencv slips to 9 5 8"casing—ins tall DSA casing spool, 2- spacer spools, Riser, Bop's, choke and kill lines, Hook up Koomey lines. Tbg = zero psi, Tbg X 9-5/8" = zero psi, 9-5/8" x 13-3/8" = 0 psi, 13-3/8" X 20" = 160psi. 10/27/13-Sunday Finished torqueing bolts on all flanges, install bell nipple, Function test BOPE. Fill stack and choke, Test all flanges to 250/3000 psi (charted). Cleaned up tools and organized cellar and wellhead room. RIH and screw into RTTS. Unseat RTTS (well static), POOH and L/D RTTS assembly. POOH w/ 15 stands D.P. M/U Casing cutter BHA, 8-1/4" multi-string cutter, X.0 sub, Stabilizer, String magnet, X.O., total length=17.08'. RIH WLcutter assembly and tag CIBP at 3 684'_. _Located collar at 3,624', positioned cutter at 3,634'. Changed out shaker screens to handle flow. Got parameters, up wt= 135k, down wt= 130k, rot wt= 132k, 60 rpm/ 3k torque, 60 spm= 700psi. Cut casing 3,634'- 3,634.5'. CBU to clean hole. POOH wet. L/D cutter BHA. M/U spear BHA, 4.5" bullnose, 9-5/8" spear packoff assm, Bowen itco spear, spear extension, 10-3/4 stop ring, X.O., X.O., total length= 19.68'. Engage spear in 9-5/8" casing. Set spear and work up to 325k (25k increments), work fr: 100k-325k several times while heating wellhead w/ steam. Estimated wt of casing after cut=130k. Tbg = zero psi, Tbg X 9-5/8" = zero psi, 9-5/8" x 13-3/8" = 0 psi, 13-3/8" X 20" = 160psi. Hilcorp Alaska, LLC Hih.orpAla.kaA.( Weekly Operations Summary Well Name API Number lWell Permit Number IStart Date End Date AN -17A 50-733-20311-01-00 213-049 10/8/2013 Daily Operations: 10/28/13 - Monday Steam heating casing spool. Working up to 325K in attempt to pull casing hanger free. Unlatch spear, POOH. Added hydraulic jars and bumper sub to BHA, total length= 40.66'. RIH and set spear, Jarring at 250k, Straight pull to 325k,+/- 50 times, Jarred at 250k, Straight pulled to 350k, 375k, and 400k, Pulled free, After pulling free up= 175k. Circulated hole volume / 5 bpm=130 psi.; Monitor well (static). Pulled hanger to rig floor, L/D jars and bumper sub, (slight flow in well). M/U 1 jt D.P., Safety valve, X.O. RIH and shut in annular on D.P. Pumped 2.7 bpm/ 200 psi while weighting up system to 9.7 ppg. Flow check well (static). Pull 9-5/8" casing stub to Rig floor. R/U casing handling equipment. L/D Spear and 9-5/8" casing sub, stub length= 22.13'. Wind blowing around 45-50 MPH, shutdown due to high winds. Installed floor safety valve. Screwed in top drive circ at 2.5 bpm at 40 psi, Clean Rig. Jim Regg, AOGCC, waived witness of BOP test on 10/28/13 at 15:30 hrs" Tbg = zero psi, Tbg X 9-5/8" = zero psi, 9-5/8" x 13-3/8" = 0 psi, 13-3/8" X 20" _ 165 psi. 10/29/13 -Tuesday BOP test delayed due to weather and wind issues. While waiting on weather to subside, cleaned and organized rig floor and mud pit areas. Circulated@ 2.5bpm/ 40psi. POOH with 9-5/8" casing to 3,298'. Well started U tubing out of casing. While circulating@ 5bpm/ 60psi, observed 1-2 bbls solids over shakers, circulated till hole cleaned up. POOH with 9-5/8" casing to surface. 86 jts, 3 pup jts, Cut off jt= 10.6'. Clean and clear rig floor of casing handling equipment. Tbg = zero psi, Tbg X 9-5/8" = zero psi, 9-5/8" x 13-3/8" _ 0 psi, 13-3/8" X 20" =170 psi. Hilcorp Alaska, LLC ,laJka.LIA Weekly Operations Summary Well Name API Number Well Permit Number Start Date EndDate AN -17A 50-733-20311-01-00 213-049 1 10/8/2013 Daily Operations: 10/30/13 - Wednesday Finish clearing floor of csg handling equipment. Pump out drain & rinse stack. Perform weekly BOPE test as per AOGCC. Tested rams 250 psi low / 3,000 psi high. Witness of test waived by Jim Regg, AOGCC. L/D test jt. Set wear ring w/ 12.5" ID. M/U BHA #4, 12.25 bit, 12.125 stab, Bit sub W/ fit, Bumper sub, Jars, X.O., 9-D.C.'s,X.0, X.O., total= 310.48'. Picked up 1st stand D.P., tested goose neck connection to 2000 psi. RIH to 1500'. C.B.U. @ 10 BPM/ 165 PSI. RIH fr 1,500' to 3,500'. Tbg = zero psi, Tbg X 9-5/8" = zero psi, 9- 5/8" x 13-3/8" = 0 psi, 13-3/8" X 20" = 165 psi. 10/31/13 - Thursday Circ, clean, warm up mud @ 3,394'& stage rate up @ 2, 8 & 10 bpm @ 220 psi w/ very little solids in returns. Rot up wt = 162k, do wt @ 145k @ 40 rpm w/ 5k tq. Wash do tag 9-5/8" stub @ 3,634' RKB DPM, Circ Clean @ 12 bpm, Flow chk (ok) pump dry job. POOH. L/dn part of Bha (secure well) while crane off loads 9-5/8" csg to boat. Finish I/dn of complete Bha #4. Clean and clear rig floor. R/U tbg handling equipment & P/U 4-1/2" tbg cmt stinger Bha #5 =821.57'. RIH to 3,533'. Start washing fr: 3,533' to tag CIBP 3,684', up wt=135, down wt= 130, rot wt= 135, 10 bpm= 125 psi, 40 rpm= 3500 torque. Circulate to clean hole and pre -treat mud system, pumping 10 bpm@ 125 psi. R/U cement head and equipment. 13-3/8" X 20" = 165 psi. 11/01/13 - Friday Finish r/up cmt head & lines. PJSM go over cmt job - Plug plan. Brk circ & fluid pack choke & gas buster. Pressure test lines 250- 4000 psi (ok). SLB pump 20 bbls of 13 ppg mud push & hold in place w/ 400 psi on choke. SLB mix & batch up tub of 16.4 ppg cmt & chk weight (ok). Dn hole w/ cmt mixing on the fly total 67 bbis of 16.4 ppg G+.2gpsD47 +.1 gpsD80 + .2gpsD168 +.01gps D177 cmt + 5 bbis of 13 ppg Mud push and displaced w/ 55 bbis 9.7 ppg mud & held in place w/ 1000 psi on choke (as cmt rounded corner released pressure & begin rotation @ 40 rpm w/ no losses to formation. CIP @ 09:30 hrs w/ ETC @ 3,200'. Pooh slow (dry) t/ 2,715'. Pump wiper ball @ 8 bpm & 40 rpm. Brk do cmt head & lines. Pooh stand back dp. R/up tbg handling equipment. L/D 4-1/2" tbg stinger. L/dn tbg cmt stinger. R/D handing equipment. Flush all HP piping w/ water & blow do same. Secure well & remove MP#1 discharge "Y" strainer & section of Kill line & prep to send in for modifications. Perform rig repairs. Remove all old HP mud piping. ECT. 13-3/8" X 20" = 165 psi. 11/02/13 -Saturday Continue WOC and perform rig repairs. Assist w/ removal of old HP mud piping & install of new HP piping. Continue install of cutting dump chute. 13-3/8" Zero, 13-3/8" X 20" = 160 psi. 11/03/13 -Sunday Continue WOC and perform rig repairs. Assist w/ removal of old HP mud piping & install of new HP piping. Approx. 85 `Yo complete. Continue R/up Mud loggers. Unload boat MWD unit & mud product. Started mixing mud system(2% kcl/ clay seal/ gem gp@ 9.2#). 13-3/8" zero 13-3/8" X 20" = 160 psi. 11/04/13 - Monday Continue WOC and perform rig repairs. New HP mud line installed (except Kill line section that's getting re- worked in town). Tighten all connections & tested same. Stand pipe & hook up hose. Continue r/up of Canrig & MWD shacks. Prefab pipe supports for new HP mud line. Continue build new Gem mud system @ 9.2 ppg, 700 bbis built. Unload work boat with primary tools, HWDP jars & kill line section - install same. Start install pipe supports on new mud line system (95% done). R/U jet heater trunk system. 13- 3/8" = zero 13-3/8" X 20" = 160 psi. r�A 117 AwrA CA KHilcorp Alaska, LLC kIa-kit .►.►.11 Weekly Operations Summary Well Name JAPI Number lWell Permit Number IStart Date End Date AN -17A 50-733-20311-01-00 213-049 1 10/8/2013 Daily Operations: 11/06/13 - Wednesday Continue fabrication & install of (2) HP mud line pipe supports @ mp & one repair on rig floor. M/up std and Flush HP piping w/ opened pipe @ max pump rate 20 bpm @ 75 psi. Chk complete mud flow system (ok). Stage rate F/ 2bpm T/ 5.5 bpm @ 450 psi thru rig floor mud manifold & bleeder to chk HP piping for vibration. Build 5-1/2" test jt. Pull wear ring & set test plug. Test BOPE's 250 psi low / 3000 psi high as per Guy Schwartz w/ AOGCC - change from approved plan. Witness of test waived by Jim Regg, AOGCC. One Fail pass on initial low test (had leaking LDS) tighten gland nut & re -test ok. Accumulator test, 3000 psi start, 1600 psi after shut in, 200 psi increase 22 sec, full pressure 86 sec. Break down test joint & blow down surface equipment. Set Wear bushing. Prep to P/U BHA. Welder installing pad eyes on the rig floor to secure the HP manifold. Change handling equipment for BHA. Secure mud manifold with chains and binders. Take measurements to mount stiff arms & SLB directional screen. P/U Drilling BHA #1, 9 5/8" Motor, NM stab. Telcom hook up phone & e-mail to mud, lab, MWD, & mud loggers shacks. Finish building 980 bbls of Gem mud @ 9.2 ppg. 13-3/8" X 20" = 110 psi. 11/07/13 - Thursday Continue P/up Drilling bha #1. Kick-off bha T/ 750'. Shallow test same(ok). Cut & slip drill line. Cut 80'. Inspect brakes and drawworks. Install blind plate on cuttings in board chute. Install cmt stand pipe double wing & lower stand pipe. R/U pipe spinners. Work on plumbing in flow box jets & TT fill line. Trip in hole F/ 750' T/ 2,600'. 4 Break circ & stage up pumps T/ 600 gpm @ 840 psi. While shearing out mud. AN -17A = 13-3/8 X 20" = 95 psi. 11/08/13 - Friday Continue washing & reaming f/ 2,600' found small cmt stringer @ 3 150' Tag firm cmt @ 3.198'w/ 15k wob @ 14.2 -bpm @ 1100 psi & 40 rpm drill cmt t/ 3,349'. Mud covered bad work pipe, reduce rate, screen & water back and work thru cmt Contamination. Work rate up t/ 10 bpm. Drlg cmt & buried std f/ 3,349't/ 3,368' work pipe & Chk MP suctions screens. Drill cmt w/ one pump @ 10 bpm f/ 3,368't/ 3,463'. Work pipe Circ btm up, reduce rate & work thru cmt Contamination. Drill cmt @ 15.5 bpm @ 1450 psi. f/3,463' t/3,530'. Displace well to 9.2 GEM mud while dumping pits overboard. Clean pits, shakers, all surface lines, & Flow box. Clean suction & discharge screens. Fill pits with new mud. AN -17A = 13-3/8 X 20" = 95 psi. 11/09/13 -Saturday Finish transfer Mud volume from RPM to rig pit active system. Brk circ & stage pump rate up to drilling rate & sheer mud. Retrieve tool face & orient same t/ 130R time drill off cmt plug @ 16 bpm @ 1000 psi & 5k on bit f/ 3,534't/ 3,634' Up wt @ 175k & do wt 160k starting @ 6 FPH monitoring formation. Working up t/ 10, 15 & 20 FPH. Slide & rot f/3,634' t/3,756' - 122' AV ROP 20.3 FPH @ 700 gpm, 1023 psi, 15-20 WOB 40 rpm, 9-12 tq on, 6k off, UP/DN/ROT 195/160/167 MW IN 9.2 MW OUT 9.3. Slide & rot f/3,756' t/ 3,900' - 144' @ AV ROP 32 FPH, 710 gpm, 15-20 WOB 1023 psi, 40 rpm, 9-12 tq on, 6k off, UP/DN/ROT 195/160/167 MW IN 9.3 MW OUT 9.3+. Slide & Rot f/ 3,900't/ 3,951'- 51' AV ROP @ 34 FPH 790 gpm, 18-22 WOB 1500 psi, 80 rpm, 9-12 tq on, 6k off, UP/DN/ROT 195/160/167 MW IN 9.3 MW OUT 9.3+. Sliding 25% of each stand. We are currently .25' below the line and 6.19 left of line. AN -17A = 13-3/8 X 20" = 95 psi. 11/10/13 -Sunday Slide & Rot f/ 3,951't/ 3,966'- 15' AV ROP @ 15 FPH 650 gpm, 18-22 WOB 1500 psi, UP/DN/ROT 195/160/167 MW IN 9.3 MW OUT 9.3+; Rot F/ 3966'T/ 4427' 461 ' AV ROP @ 42 FPH 650 gpm, 22-35 WOB 1500 psi, 80 rpm, 9-12 tq on, 6k off, UP/DN/ROT 205/180/190 MW IN 9.4 MW OUT 9.4+. Slide first 30'. Rot f/ 4,427't/ 4,481'- 54' AV ROP @ 36 FPH 650 gpm, 22-35 WOB 1500 psi, 80 rpm, 9-12 tq on, 6k off, UP/DN/ROT 205/180/190 MW IN 9.4 MW OUT 9.4+. Swab went out of pump one. Brought centrifuge online. Circ btm up until clean @ 387 gpm. POOH f/4,481' t/ 4,000' pulling 30k over. Work pipe down to control swabbing. POOH f/ 4,000' t/ 3,450' clean with proper pipe displacement. Work on changing swabs & liners in both pumps to ceramic 6". Troubleshoot dump valve in sand trap. Service rig and TD. Continue to change liners in pumps #1 & #2 to ceramic 6". Adjust breaks on the drawworks. r�A 117 AwrA CA or Tit, THE STATE Alaska Oil and Gas °fALASKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Luke Keller q 73 Drilling Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive Anchorage, AK 99503 Re: Granit Point Field, Middle Kenai Oil Pool, Granite PT ST 18742 17 Sundry Number: 313 -143 Dear Mr. Keller: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 244 t4 z.,.4 4 ,_ Cathy . Foerster Chair DATED this hay of April, 2013. Encl. SCANNED APR 12 2013 14 E STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill J - Perforate New Pool p Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pun Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re - enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Dill Number. Hilcorp Alaska, LLC Exploratory ❑ Development Er ?0 1770750 3. Address: Stratigraphic ❑ Service ©•{ci`t13 6. API Number. 3800 Centerpoint Drive, Suite 100, Anchorage, AK, 99503 50 733 - 20311 • 7. If perforating: N/A 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? A.#. 1� i3 Will planned perforations require a spacing exception? Yes ❑ No ❑ 604A k Pr Sr 'VI a - 17 9. Property Designation (Lease Number): 10. Field /Pool(s): 6p00Niilr- P7 Al rd./ /4 kno. , • Oil ADL018742 11. PRESENT WELL CONDITION SUMMARY � Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): !1I Plugs (measured): Junk (measured): • 10,674' • 9,972' • 10,400' 9;972' f?oy' N/A N/A Casing Length Size MD TVD Burst Collapse Structural 30" Conductor 610 20" 610' 609 2110 psi 520 psi Surface 3514 13 -3/8" 3514' 3445' 2730 psi 1130 psi Intermediate Production 10663' 9 -5/8" 10663' 10389' 6820 psi 3330 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): • 9660' to 10,334' 9016' to 9638' 3 -1/2" L -80 9612' Packers and SSSV Type: Baker F -1 Pkr, 4.75" SB, w/ seal assy Packers and SSSV MD (ft) and TVD (ft): Pkr depth: 9591' MD 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program Q BOP Sketch El . Exploratory ❑ Stratigraphic ❑ Development _ Service [r - . 14. Estimated Date for 15. Well Status after proposed work: O June 15th, 2013 Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended Ej 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned Commission Representative: GSTOR ❑ SPLUG LJ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Email Printed Name Luke Keller Title Drilling Engineer Signature r Phone (907) 777 -8395 Date 3/15/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 ,.. 7D 1 43 Plug Integrity E BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ ` Other: 'le 360° "S L. 80r /G o' PROMS APR 1 2 20 Spacing Exception Required? Yes ❑ No [i Subsequent Form Required: / o - 1c 7 ! APPROVED BY 9 Approved by: /2 COMMISSIONER THE COMMISSION Date: 4.-// ..73 we- /3 Submit Form and k t,?) db O Approved application is valid for 2 months from the date of approval. ' zif / .4t, ttachmenrs in Duplicate tAN,' • • Hilcorp Alaska, LLC Anna 17 Slot Recovery Program Anna Platform Rig 428 Granite Point Field Revision 0 March 13 2013 . ‘ • Anna #17 Slot Recovery Procedure Hilcor ER Contents 1.0 Background / Objective 2 2.0 Plug & Abandonment Plan Summary 2 3.0 Well Information 3 4.0 BOP Test Summary 4 5.0 Kill Well / N/D Tree 5 6.0 BOP Installation & Test 5 7.0 Pull 3-1/2" tubing and P &A wellbore 6 8.0 P &A Contingency (Option #1) 7 9.0 P &A Contingency (Option #2) 8 10.0 Cut and Pull 9-5/8" casing 9 11.0 Set kick -off plug 11 12.0 BOP Schematic 15 13.0 Wellhead Schematic 16 14.0 Anna Slot Diagram 17 15.0 Existing Wellbore Diagram 18 16.0 Planned Wellbore Diagram 19 17.0 Anna 17 Directional Survey 20 18.0 MASP Calculations 21 • • • Anna Platform #17 Slot Recovery Procedure Hilcorp comp.) 1.0 Background / Objective Anna 17 has been identified as a candidate for redrilling, targeting the Hemlock formation to the South. Integrated subsurface and 3 -D geological interpretations, in conjuction with subsurface and previous production data indicate that oil reserves are unbooked and not recoverable in existing wellbores. Anna 17 is currently shut in. It was last utilized as a water injector. Communication between the 3 -1/2" tubing and the 9 -5/8" casing was observed in 1998. An attempt was made to get a MIT of the welibore, but 1.75" tools were unable to pass below 1588'. It is suspected that the packer / seal assy / tubing is leaking, putting the tubing ID in direct communication with the 3 -1/2" x 9 -5/8" annulus. Objectives of the slot recovery are: • Permanently plug and abandon the Anna 17 welibore to a depth of 3,664' MD. • Cut and pull the 9 -5/8" casing to a depth of 3614' MD (100' below the 13 -3/8" shoe). / • Set a cmt plug from 3664' to 3314' MD. '/ 2.0 Plug & Abandonment Plan Summary The following procedure covers steps necessary to: • Kill well, Remove tree, N/U & test BOP. • Pull 3-1/2" tubing. • P &A welibore with cement. • Set & test CIBP at 3664'. • Cut and pull 9-5/8" casing to 3614' MD. • Clean out run with 12 -1/4" clean out assy. • Plug back well with cmt to 3314' MD. A separate drilling & completion procedure will be issued that details the drilling and completion of Anna 17RD as follows: • Drill 12 -1/4" hole to 10,700' MD / 10,237' TVD. Run and cmt 9 -5/8" production casing. • Drill 8 -1/2" hole to 13,342' MD / 11,304' TVD. Run and cmt 7" production liner. • Complete well with dual string. 1 Coa(vr. 4/.eif waf fft ovt/ /`c%ay I G' /77Y111 C / /ep/fr Cceed Av# 1"-ork 1 . 4 5 f% off °"( y C4.4 44 ry /14419,A47 C eCO,0p YA/,' Page 2 of 21 Revision 0 March, 2013 11 Anna Platform #17 Slot Recovery Procedure HilCOr xr 3.0 Well Information Well Anna 17 Anna Leg & Slot designation Leg #2 (East Corner), Slot #5 Current Completion Type: 3 -1/2" Production Tubing to 9,612' MD Field / Reservoir Name: Granite Point Field / Middle Tyonek C Oil Pool Well TD, MD / TVD: 10,674' MD / 9,972' TVD PBTD 10,400' MD / 9,704' TVD Maximum Anticipate Surface Pressure: 1341 psi Current Reservoir Pressure (estimated): 2195 psi Reservoir Temperature: 160 deg F 9 -5/8" x 13 -3/8" Annulus Pressure: 263 psi (3 -14 -2013) 9 -5/8" x 3 -1/2" Annulus Pressure: 0 psi (3 -14 -2013) 3 -1/2" Tubing Pressure: 0 psi (3 -14 -2013) Work String: 5" 19.5# S -135 NC -50 (Rental string from Weatherford) RKB — MSL: 121' AMSL RKB — THF: 43' Water Depth 71' P &A AFE No.: TBD P &A AFE Amount: TBD Drilling Contractor/Rig Name: Kuukpik / Rig 428 Page 3 of 21 Revision 0 March, 2013 • • Anna Platform #17 Slot Recovery Procedure Hi1CO� r 4.0 BOP Test Summary The AOGCC has specified that Hilcorp operations follow a (1) week test frequency throughout the slot recovery phase. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. Test BOP equipment to 250/3000 psi for 5/5 min (annular to 50% rated WP, 2500 psi on the high test). Hole Section Equipment Test Pressure (psi) • 13 -5/8" Shaffer 5M annular • 13 -5/8" 5M Schaffer LXT Double gate Initial Test: o Top Cavity: 2 -7/8" x 5-1/2" VBR 250/3000 o Btm Cavity: Blind Ram (Annular 2500 psi) Slot Recovery • Mud cross • 13 -5/8" 5M Cameron U single gate Subsequent Tests: o 9 -5/8" fixed ram 250/3000 • 3-1/16" 5M Choke Manifold (Annular 2500 psi) • Standpipe, floor valves, etc Required AOGCC Notifications: 24 hours notice prior to spud 24 hours notice prior to testing BOPs 24 hours notice prior to cement operations Page 4 of 21 Revision 0 March, 2013 • • 11 Anna Platform #17 S lot Recovery Procedure Hilcorp Energy Company 5.0 Kill Well / N/D Tree 5.1 Prior to skidding rig onto leg #2, slot 5: 5.2 Check 3 -1/2" x 9 -5/8" annulus for pressure. Check 3 -1/2" tubing for pressure. 5.3 Conduct a pressure test of the 3 -1/2" x 9 -5/8" annulus to 500 psi / 30 min. 5.4 Install and test lubricator on tree. R/U E -line & tbg punch. • Punch holes in 3 -1/2" tubing at 9550' (F -1 pkr at 9591' MD). • POH, R/D E -line. 5.5 Ensure necessary flange(s) installed on tubing head side outlet (9 -5/8" x 3 -1/2" annulus) to facilitate circulating hose installation. 5.6 R/U and pump 2X annular capacity down annulus, bullheading into formation. 5.7 Line up to pump down tubing — bullhead 2X tubing capacity to clear production tubing. • 5.8 Pump 2X B/U, taking returns from production annulus to shakers & to mud pits. • • Note loss rate. Spot sized salt pill at perfs if necessary. 5.9 Install a (2) way check valve in tubing hanger. Test above (2) way check to 3000 psi. • 5.10 N/D production tree. • Check and clean lift threads on tubing hanger. 5.11 Skid rig over leg #2, slot 5. 6.0 BOP Installation & Test 6.1 N/U 13 -5/8" 5M BOP assy configured as follows: o BOP configuration f/ top down: Annular / Double Gate / Mud Cross / Single Gate • Double Ram: 2 -7/8" x 5 -1/2" VBR in top cavity, blind ram in bottom cavity. • Single Ram: 9 -5/8" fixed casing ram. • o N/U bell nipple. 6.2 Run BOP test assy, M/U to hanger lift threads & test BOPs to 250/3000 psi for 5/5 min. a. Test annular on 3 -1/2" test joint to 250/2500 psi for 5/5 min. b. Test VBR on 3 -1/2" and 5" test joint c. L/D test assy. d. Test blind rams against (2) way check. 6.3 Pull TWC. Page 5 of 21 Revision 0 March, 2013 • • • Anna Platform #17 Slot Recovery Procedure Hilcorp El 'KV company 6.4 Mix 400 bbl 9.5 ppg drilling fluid in preparation for casing cutting and pulling operations. 7.0 Pull 3 - 1/2" tubing and P &A wellbore. 7.1 R/U Weatherford casing crews for handling 3 -1/2" tubing. • Ensure a XO to 3 -1/2" SCBT (Special clearance buttress tubing) is on the rig floor and M/U to FOSV and ready to be stabbed. 7.2 M/U 3 -1/2" tubing hanger landing joints & RIH. M/U to tubing hanger. 7.3 Pull tubing hanger. • Ensure there is no trapped pressure on the 9 -5/8" x 3 -1/2" tubing annulus. . • Max overpull on the 3 -1/2" 9.2# SCBT is 159,090 Ibs. 7.4 POOH & L/D 3 -1/2" 9.2# SCBT tubing. • Install thread protectors on both ends. • Keep 1500' in the derrick to use as a cmt stinger. 7.5 Send the hanger in to the "Squirrel Hut" for inspection & cleaning. . 7.6 M/U 1500' 3 -1/2" cmt stinger. RIH and sting through F -1 pkr at 9591' MD. Continue in hole to position bottom of cmt stinger at PBTD - 10,400' MD and crossover to DP at 8,900' MD. • Note: There is suspected damage to the casing at 10,015' and 10,265'. If unable to pass either depth, stop here and proceed with cmt job. Proceed with the same volumes, a slightly higher TOC is okay. 7.7 CBU and prep for cmt job. 7.8 Balance a 7_bbl, 15.4 ppg cmt plug from 10,400' to 9400'. ° � S ? s ' 7.9 TOH to 9000' MD. Drop a DP wiper ball, circ B/U and rotate string to clear of cmt. 7.10 TOH to cmt stinger. M/U RTTS and hang off 1500' cmt stinger below mud line. Test above RTTS to 3000 psi / 15 min. 7.11 N/D BOP. N/D tubing head. Tack weld 9 -5/8" casing slips to 9 -5/8" casing stub to ensure slips come out with the casing when pulled. 7.12 Install 13 -5/8" 3M x 13 -5/8" 5M spool. N/U BOP, test new breaks to 250 / 3000 psi for 5/5 min. Test against cup tester and VBR (or annular). 7.13 Pull RTTS, ensure to check for pressure build up below before unseating as pressure may have built up below the packer during cmt curing process. POOH and L/D RTTS. / 7.14 TIH and tag plug w/ stinger. Close pipe ram and test casing to-560 psi / 30 min. Note amount of weight set on plug, and MD plug tagged at. /v0+' s74.,..,44-y- Page 6 of 21 Revision 0 March, 2013 • • Anna Platform #17 Slot Recovery Procedure Hilcor 7.15 If TOC is not located by 9560' (100' above top perf, top perf is at 9660' MD), we will have to locate TOC and balance another cmt plug. 7.16 TOH and L/D cmt stinger. 6 7.17 R/U e -line and set CIBP at 3664' MD. Test CIBP tghOpsi / 30 min. 8.0 P &A Contingency (Option #1) Note: Proceed with contingency if the 3-1/2" seal assy will not pull free of the F -1 Paker at 9591'. 8.1 R/U E -Line and tubing cutter. Cut 3 -1/2" tubing at 9550'. TOH, R/D tubing cutter and E -line " unit. 8.2 POOH and L/D 3 -1/2" tubing hanger. , 8.3 M/U Pump in sub and line up to pump down 3 -1/2" tubing. Circ (1) B/U prior to cmt operations. d , 8.4 Close pipe ram on 3 -1/2" tubing. Pump 100 b1�15_4 ppg cement down tubing (bullheading into perfs). Displace cmt with FIW using cmt unit. Manipulate choke position to maintain a small amount of backpressure to keep cmt from outrunning displacement. 8.5 Displace cmt with FIW using cmt pump until approx. 10 bbls cmt is left inside the tubing. Balance the remaining 10 bbls cmt outside the 3 -1/2" tubing (9450' to 9314'). 8.6 TOH to 8000' (L/D 3 -1/2" tubing). CBU. Cont POH & L/D prod tubing to 1500'. 8.7 M/U crossover and RTTS. Proceed with step 7.10 above. 8.8 TIH w/ gauge cutter & weight bars. Locate TOC (estimated at 9314'). Pressure test casing to SW si/ 30 min. __� �� 'k ?r. ," 8.9 / Set CIBP at 3664' MD. R/D E -line. Test CIBP topsi / 30 min. Page 7 of 21 Revision 0 March, 2013 • Anna Platform #17 Slot Recovery Procedure EnaV Hilcorp 9.0 P &A Contingency (Option #2) Note: Proceed with contingency if the 3 -1/2 " seal assy will not pull free of the F -1 Paker at 9591 '. 9.1 R/U E -line and tubing cutter. Cut 3 -1/2" tubing at 9550'. TOH, R/D tubing cutter and E -line unit. 9.2 POOH and L/D 3 -1/2" tubing hanger and 3 -1/2" tubing. 9.3 M/U and RIH w/ cmt retainer on 5" work string. Set cmt retainer at 9540' MD. 9.4 Mix and pump 100 bbls 15.4 ppg cmt. Bullhead 90 bbls below cmt retainer, dump 10 bbls on top of cement retainer. Unsting and pull up to 9000'. Drop DP wiper ball and CBU. 9.5 TOH to 1500'. 9.6 Proceed with step 7.10 above. 9.7 TIH w/ gauge cutter & weight bars. Locate TOC (estimated at 9403'). Pressure test casing to psi/ 30 min. --- A1 {. 4—kre 9.8 RIB and set CIBP at 3664' MD. Test CIBP to 5.®O'psi / 30 min. . lr • 17 Page 8 of 21 Revision 0 March, 2013 • • Anna Platform #17 Slot Recovery Procedure HiteOI Ear 10.0 Cut and Pull 9 -5/8" casing 10.1 Check pressure on 9 -5/8" x 13 -3/8" annulus. If pressure is not zero, notify drilling engineer or . drilling manager. 10.2 M/U below casing cutting assy: - BHA Connection Length OD 8 -3/8" OD Non rotating stab 8 -1/4" multi string cutter with 3.5" tungsten carbide knives 8 -3/8" OD Non rotating stab Float Sub Magnet 5 "DP • Ensure that the max opening of the multi - string cutter has been tested with a ring gauge in the shop. We do not want to cut the 13 -3/8" casing. • Surface test the multi string cutter prior to running in the hole. Bring the flowrate up slowly and record the minimum flowrate to fully open the knives. • Once the test is completed, secure the knives in the retracted position prior to running in the hole to prevent inadvertent extension and possible damage to the knives. • RIH at a moderate speed. 10.3 TIH to position casing cutters at —3614' MD. Locate nearest coupling with cutters and ensure a cut is not made at a connection. 10.4 Displace well to 9.5 ppg mud. • Note: this mud system will not be used to drill with. We will dump this system prior to drilling the 12 -1/4" hole section. 10.5 Ensure to have magnets rigged up in ditch to catch metal debris. 10.6 Record P/U and S/O weights, establish free rotating torque at the recommended cutting rpm (80 rpm). 10.7 Slowly bring on pumps to 500 psi. The cut will be made when a pressure drop is seen. • It is anticipated to take 15 — 30 minutes to perform the cut. If the casing is free and in tension, the stand pipe pressure loss will be sudden. If the casing is stuck or in compression, the pressure decrease will be more gradual. • Monitor the 9 -5/8" x 13 -3/8" annulus pressure while cutting the casing. An imbalance in MW may show up at the gauge. Page 9 of 21 Revision 0 March, 2013 • • • Anna Platform #17 Slot Recovery Procedure Hilcor. sr 10.8 Shut off mud pump. Monitor well on trip tank for 15 min. Ensure the annulus has no pressure. CBU to see if any gas has migrated into the wellbore. 10.9 Close pipe ram and attempt to circulate down the 9 -5/8" casing, taking returns at the casing head side outlet (9 -5/8" x 13 -3/8" annulus). • If communication is observed, circ a few B/U depending on flow rates that can be achieved. • If communication is not observed, pull up to 3500' and cut casing again. • Attempt to circulate again down 9 -5/8" and up 9 -5/8" x 13 -3/8" annulus. • If circulation is still not possible, consult with Anchorage drill team for plan forward. 10.10 POOH w/ casing cutter assembly. Rack back knife assy in derrick if possible. 10.11 M/U flush tool and flush out debris from behind the 9 -5/8" casing stub in the wellhead. POH w/ flush tool. 10.12 RIH w/ 9 -5/8" casing spear and engage 9 -5/8" casing. BHA Connection Length OD Spear Pack -off Itco Spear 9 -5/8" 47# spear grapple Spear extention Spear stop sub 10.13 Slowly P/U on the casing hanger. • Determine weak point in string. 9 -5/8" 47# L -80 BTC casing yield strength is 1,086k • If unable to pull hanger, discuss forward plan with Anchorage Drill Team. 10.14 L/D Spear assy. POOH and L/D 9 -5/8" casing. Page 10 of 21 Revision 0 March, 2013 • • 111 Anna Platform #17 Slot Recovery Procedure Hilcorp BRIT/ C 11.0 Set kick -off plug 11.1 M/U below clean out assy and TIH to top of 9 -5/8" casing stub at 3614' MD. BHA Connection Length OD 12 -1/4" mill tooth bit Near bit stab (12 -1/8) 8 "DC String stab (12 -1/8" 2x8 "DC XO 5 HWDP Jar 9 HWDP 11.2 Tag the top of the 9 -5/8" stub lightly. Do not set down more than 5k or rotate the string with weight down on the stub. • Pump viscous sweeps as necessary to carry debris / scale out of the wellbore. • Rotate and reciprocate string while circulating as necessary to clean up hole. The objective is to clean out as much old mud and settled solids as possible to allow the sides of the kick -off plug to touch the original 12 -1/4" bore hole. 11.3 TOH w/ clean out assy. 11.4 TIH w/ 800' x 4 -1/2" cmt stinger. Have a 4 -1/2" diverter sub built ahead of time to be run on btm. Lightly tag the casing stub @ 3614' and make an effort to enter the 9 -5/8" casing, TIH to the CIBP at 3664' MD. It unable, proceed with cmt job with diverter sub at 9 -5/8" casing stub. 11.5 R/U side entry pump in sub. • Ensure that rotation will be possible while pumping and displacing cement!!! This is critical to getting a good, hard kick off plug. 11.6 Break circulation, and circ bottoms up. Pump at 12 —14 bpm, and rotate at 80 rpm while circulating B/U. Again, the objective is to clean up the hole in preparation for cementing. Page 11 of 21 Revision 0 March, 2013 • • Anna Platform #17 Slot Recovery Procedure Hilcorp Energy Company 11.7 Cement Calculations: Section Formula Volume 13-3/8" ID x 4-1/2" cmt (3514' — 3314') x 0.1325 = 26.5 bbls stinger overlap: 12-1/4" OH x 4-1/2" cement stinger: (3614' - 3514) x 0.126 x 1.5 = 18.9 bbls 9-5/8" ID x 4-1/2" cement (3664' — 3614') x 0.054 = 2.7 bbls stinger: 4-1/2" ID for balanced o plug: (3664' - 3314') x 0.0146 = 5.1 bbls Total Volume (bbls): 26.5 + 18.9 + 2.7 + 5.1 = 11.8 Slurry Information: Stage High Density Kick Off Plug System 17 ppg Class G Density 17 lb/gal Yield 1.0 ft3 /sk Mixed Water 3.85 gal /sk Mixed Fluid 3.877 gal /sk Expected 100 Bc at 04:30 hr:mn Thickening Expected ISO /API < 150 mL Fluid Loss Code Description Concentration Additives D -046 Antifoam 0.2% BWOC D -065 Dispersant 1.0 % BWOC D -167 Fluid Loss 0.2% BWOC D -800 Retarder 0.3% BWOC 11.9 Mix and pump 30 bbls 12 ppg mud push II spacer 11.10 Mix and pump 53.2 bbls 17 ppg cement. Rotate the string at 40 — 60 rpm while pumping cement. Ensure to keep density as close to 17 ppg as possible. 11.11 Displace with 3 bbls 12 ppg mud push spacer & 49 bbls 9.5 ppg mud. • Calculated displacement is 54 bbls mud & 3 bbls mud push. • We want to leave displacement about 5 bbls short of a balanced plug to ensure the pipe is dry when pulling up above the plug. • When displacing cmt, rotate the string at 40 — 60 rpm. • Pump at 8 — 10 bpm. Reduce pump rate to 2 bpm for the last 5 bbls. • Displace with the CMT UNIT AND NOT THE RIG PUMPS Page 12 of 21 Revision 0 March, 2013 • • Anna Platform #17 Slot Recovery Procedure Hilcorp Energy Company 11.12 Displacement calcs and diagram: Note: Calculations below assume gauge hole and highest possible cement plug. Section Capacity (bpf) 13- 3 /8 "csgx4 -1/2 "Ann Cap: 0.128 W 12 -1/4" OH x 4-1/2" Ann Cap: 0.126 b..Q,f.. 9-5/8" csgx 4 -1/2" Ann Cap: 0.0535 4-1/2" Cap: 0.0146 b„pf 2864' Section Formula Top 3084' Mud Push:13-3/8" x 4-1/2' 30bbls /(0.128 +0.0146)= 3264' cmtstingeroverlap: 210 ft 3084' 3264 ft-210 ft= 3084 ft Cmt 13- 3/8"x4- 1/2 -cmt (53.2- 17.5) /(0.128 +0.0146)= stinger overlap: 250 ft 3264' 3514' —250 ft= 3264 ft 3514' Cmt 124/4" OH x 4-1/2" cmt (0.126 + 0.0146)x 100' =14.1 3514' stinger: bbls Cmt 9 5 /8" x 4 -1/2" cmt (0.0535 + 0.0146)x 50' =3.4 bbls 3614' 3614' stinger: 3664' Section Formula Disp 5" Drill Pipe (Mud): 2864' x.01776 OA= 50.9 bbl cmt stinger (Mud): (3084' — 2864') x.0146 = 3.2 bbl 4 -1/2" cmt stinger (mud push): 180' x .0146 bpf= 2.6 bbl 11.13 TOH slowly to position the btm of the cmt stinger at 2500' MD. 11.14 Drop DP wiper ball and CBU (long way) at 15 — 20 bpm. Rotate pipe at 40 — 60 rpm to ensure cmt is removed from the drill pipe. 11.15 TOH & L/D cmt stinger. t 103O p Zc: 11.16 WOC a minimum of 24 hrs before drilling ou�. C -4 /3t c s� 11.17 M/U 12 -1/4" directional BHA. A separate procedure will be issued for the drilling and completion of Anna 17RD which includes: Page 13 of 21 Revision 0 March, 2013 • • Anna Platform #17 Slot Recovery Procedure Hilcorp EnaV • Drill 12 -1/4" hole to 10,700' MD / 10,237' TVD. Run and cmt 9 -5/8" production casing. • Drill 8-1/2" hole to 13,342' MD / 11,304' TVD. Run and cmt 7" production liner. • Complete well with dual string. Page 14 of 21 Revision 0 March, 2013 • • Anna Platform #17 Slot Recovery Procedure Hilcorp Enemy Company 12.0 BOP Schematic (Stack up on left will be used while pulling 3 -1/2" prod tubing, Stack up on right will be used after removing tubing head). W t u At n o t Ov pzN .ea. not r AO Fw 7 7 • .,,,• I p t sill e 1 i . r . i I i t r i∎ lU r. ■ r - I 1. i ': 7,4[,trYWV F' ,.: a�— 2 434 Writer 6M 2•37 v 3r .. - 1 3 3 4.-/N D am wd t/ 1 rm a ..... .. , `,. .J `-- g� g , ► , t1.R t42 '.. taarw00;18 04717k rc 11at111.e ce7u5,s6p.ire AY ti Ira= m • S .J,,,,,....., It ,.. • , i - i +.1 , meg– Willa r� 1,11 )....4 x _ i _ ..., ID V11:11 il Z Ili � � l �$�' ll� i �1 ,,. or . w. Page 15 of 21 Revision 0 March, 2013 • . • 0 Anna Platform #17 Slot Recovery Procedure Hilcorp Energy Company 13.0 Wellhead Schematic An-17 BEITA, Bowen, 3 V6 10M FE Tubing hanger, CIW-DCB- 20 X 13 3/8 X 9 5/8 X X 3" Bowen quick union FHB 11 X 3 EUE lifl X 3 '4 3 '4 EUE sup, w/ a type H BPV 11 profle, 6 ' extended neck mot i Valve, Swab. CIW / -FL, 3 1116 . el ' 10M FE, HWO, FF aim Ipt. . Allimil .„ lail.moie. • III Poll 1p Valve, lower master, CIW-FC, /OW 3 1/16 1DM FE, HWO, FF trim i , r o Adapter, CIW, 11 5M FE X lkholl 3116 10M Stdd, 6/slick III Arra. Ili neck pocket, N 0 .., Tubing head, CIW.DCB, • oum 13 5I8 5M X 11 5M, w. 2- ="i • 11 • too ill 4.4.. 2 1/16 5M SSO, X-bottom prep Valve, CIW-F, 2 1/16 5M FE, HAD 1 Qiy 2 - - .' 7411 01Milf` ' r . , , a isi 11 lel W Casing spool CIW-WF, . .1 Valve, CIW-F, 2 1/16 5M ' 21 '1%; 2M X 13 SEi 3M, , ---; ._ r FE, HWO w/ 2- 2 1/16 5M EFO, 01114i 1. v Qty 2 X bottom prep • • 1 4 ' NI _ 1 1 III J/ 111-1. !. I.: , O - 1 1101. 0 0 1 at _ • JR 1 _ Casing head, CIW-WF, IIII y ... 21 % 2M X SOW, wi , — d „ 2- 2 1116 2M EFO I * 1 = I i = 3. 4111110! II I l . • ' . Valve, CIW-F, 2 116 2M I' a FE. HWO IOW Page 16 16 of 21 Revision 0 March, 2013 . • • Anna Platform #17 Slot Recovery Procedure Hilcorp Energy Company 14.0 Anna Slot Diagram ANNA PLATFORM WELLSLOT DIAGRAM SHALE 01 /0 /1 2 SHALE WATER SHAKER SHAKER FLOOD 0 ❑ 51 7RD2 WATER FLOOD 39 0 4RD it ❑ sit r ' /,� .47 / ie 11 RD ',/// �j 28RD2 32RD 36 FIRE 1 • 5 1 r• PUMP A ._4 ---- -- ---- es 27RD ,; A_J /� 5D 37. ;9 F �._}. 17 0 s 74 1, 0 %/13 52 3RD 0 Itii 15 8 Leg #1 I t k Leg # 2 North Corner East Corner 0 f © INTAKE 0 ❑ DISCHARGE Producer Dual Gas Well Injector Completion SHALE 7 25 23RD SHAKER 46 MUCI 3 ,V, 0 SlI 0 • f, 5 r r 2 SEWAGE 19 i ` 29 WATER s � 1 ' SHALE PRODUCED , -4--'* r • FLOOD •. a : SHAKER WATER WATER WATER '6 0 FLOOD FLOOD f ' srt" 'sip ' III A 1�Si 5 V ..r 26 t 8 r" 13RD 9 J or sa . /&? .iii ' .6 4 5 33 21 0 E. wart s Leg # Leg #3 FI 1 West Corner South Corner Page 17 of 21 Revision 0 March, 2013 , • • 11 Anna Plafform #17 Slot Recovery Procedure Hilcorp Energy Company 15.0 Existing Wellbore Diagram 4111 0 Anna Platform Vis Chevron Well No. 17 Actual Completion 12/31/83 1 , CASING AND TITHING DETAIL RKB = 105 TBG Hcp = x' ...i.o WT GRADE COX ID TOP RINI. 30" x # x-55 - 19.124" Surface ' ' It I I 20 913# X-52 . 19.124" Surface 610' 1 13 34 54.5, 81, K-55 a L410 Bierregs l 247' Surface 3.5 14' 68, 72# 9-518" 40, 43.5, 15-95 BOUM BO r Surface 1003' 474 1 Tablas ti 3.1r 92# 1,00 SC1111 2.992" 0' 9.612' ,e, A , sit f', „JEWELRY DETAIL 1 NO Depth VI 00 !Um_ I . 34" - - 1 On Hangxr. Comm. 3-117. x 1U" I 35" - - -ET aRD x 3-1/2 DUO X0 2 9,59r - - Halter F.1 Pks 4,750 SR. vif Sea Assembly, 1/4/04 3 9,612' - - mule Shoe I • -.• 2 Fish/FR(4nm i Na Peath (1 eiD Length Item i...- 11■1 ximm A 10,260* 140' Tag h11 (Tagged 12131/113) .. 1 CR_ 9130" PERFORATION HISTORY • lithIlAtill Aceurn. ... Oats 1 Zone i Top 1 Bhp Amt spf Comments I 7/1411978 1 C-5 9,660' 9,725' 65 2 !leper/ - 31 Casing 12)27/1978 , C 5 9,670' 9,725' 55* 4 Reperf - 7.1f5 ' Slam Kane 12127/1978 7 :-5 9,758' 9,832" 14' 4' Rupert 2 1,16" Skm Kona .........._ 1 r25/1978 U-b 9,8841 9,86% Z 4 Repel 3-lir Casing r•—•-•1 / * 1/1711978 i C 0,883' 9,885' 2' 3 R Cr St , .. 1::,.! r 12/27/1978 C 10,114' 10 ,.I 24' i0 4 Report -2118780m1r.one i 7127/1978 ; C 10,134' 10,144' 10' 4' Rope - 240 Slim None Tot spoon ossop 10,8 1 5.._ 7 ...... z 711611978 ;;:- 4 10,21Z 10,272' 60' suspected hole In casino 47. 7i'4198 - ' 10318a 10 334' IV 2" Remelt - 3-1/6" Casing 2' Raper/- 3-118° Coining 10,265, imi 183 r_ L t l___ 0 1 in )4: TD = 100614' MO, 9,972* TWO '4 111k. 41 A t P8TD - 10,400' MI)- 9,704' TVD Ms s angle •••, 29.5° g 8,600' ' L Page 18 of 21 Revision 0 March, 2013 Anna Platform #17 Slot Recovery Procedure Hilcorp Energy Company 16.0 Planned Wellbore Diagram SCHEMATIC Steelhead Platform WELL: Anna 17 3/14/2013 t4 Casing Detail GPADE CO•N 1: TOP 151 5: X-55 • Surf 915X X-52 V l;12. 51C 15 545 91, EL K 12 3,n-f 3514" 72 X 1-99 1 • ••, V 5-5/8 4: 435 47 X 545 ET: 57751 5...irf 1C,553' V V 3 ig .,••• -mem. Item Detail • V Depth Itern 3314' Planned Top of ktck off plug 2 3.514 9-5/9' Casinp,Stul; CIBP P tanned top of PEA en-t 5;1 Baker F-1 Pk-4 75' 5! Toppe 1: e 1 -DL VPTii ' • MI■...!■61.- TD: 10,874' MD/ 9,972' TIM REVISED. 3 REVISED BY' LEE Page 19 of 21 Revision 0 March, 2013 • • Anna Platform #17 Slot Recovery Procedure Hi lc_orp mp 17.0 Anna 17 Directional Survey MD TVD Ind AZM MD TVD Ind AZM MD ND . Ind AZM 0 0 0 0 4600 4465.43 26.75 165 9200 8604.43 26.25 193 100 99.99 1 168 4700 4554.63 27 165 9300 8694.21 26 195 200 199.97 1.5 224 4800 4643.53 27.5 166 9400 8784.29 25.5 197 300 299.93 2 217 4900 4732.43 27 166 9500 8875.1 24 199 400 399.86 2.25 219 5000 4821.73 26.5 168 9576 8944.39 24.5 198 500 499.78 2.17 221 5100 4911.42 26 167 9600 8966.27 24 199.5 600 599.71 2.25 228 5200 50011 26,25 167 9700 9057.72 23.75 202 700 699.64 2.25 202 5300 5090,89 26.25 167 9800 9149.16 24 202 800 799.49 4 162 5400 5180.58 26.25 168 _ 9900 9240.87 23 203 900 899.2 4.75 151 5500 5270.26 26.25 168 10000 9333.18 22.25 207 1000 998.88 4.5 152 5600 5359.85 26.5 168 10060 9388.76 22 209 1100 1098.62 3.75 150 5700 5449.54 26 170 10100 9425.98 21 209 1200 1198.43 3.25 150 5800 5539.33 26.25 171 10200 9519.57 20.25 211 1300 1298.29 2.75 148 5900 5629.4 25.25 171 10300 9613.76 19 215 1400 1398.2 2.25 152 6000 5719.84 25.25 171 10380 9689.68 17.75 219 1500 1498.13 2 156 6100 5810.29 25.25 171 10674 9971.89 14.83 227.82 1600 1598.08 1.5 163 6200 5900.73 25.25 171 10724 10020.23 14.83 227.82 1700 1698.04 1.75 166 6300 5991,55 24.25 173 1800 1798 1.5 170 6400 6082.81 24 173 1900 1897.97 1.5 198 6500 6174.26 23.75 175 2000 1997.91 2.5 186 6600 6265.96 23.25 175 2100 2097.66 5.45 181 6700 6357.67 23.75 176 2200 2197.15 6.17 167 6800 6449.55 22.75 175 2300 2296.51 7 141 6900 6541.77 22.75 177.5 2400 2395.59 8.5 137 7000 6634.16 22.25 177 2500 2494.25 10.25 137 7100 6726.55 22.75 177 _ 2600 2592.28 12.5 137 7200 6818.85 22.5 178 2700 2689.41 15 138 7300 6911.41 22 182 2800 2785.34 17.75 139 7400 7004.05 22.25 182.5 2900 2879.96 20 139 7500 7096.27 23.25 184 3000 2973.78 20.5 139 7600 7187.8 24.25 188.5 3100 3067.52 20.25 138 7700 7278,62 2515 189 3200 3161.47 19.83 138 7800 7368.59 26.5 189 3300 3255.71 19.25 137 7900 7457.59 27.75 191 3400 3350.24 18.83 ° 135 8000 7546.39 27 191 3490 3435.57 18.25 135 8100 7634.99 28.25 192 3600 3540.36 17.17 141 8200 7722.98 28.5 191 3700 3635.67 18.08 144 8300 7810.96 28.25 192 3800 3730.81 17.83 152 8400 7899.05 28.25 191 3900 3825.84 18.5 160 8500 7986.93 28.75 191 4000 3920.18 20.25 162.5 8600 8074.29 29.5 190 4100 4013.37 22.25 162.5 8700 8161.54 29 191 4200 4105.68 23 164 8800 8248.9 29.25 191 4300 4196.76 25.75 164 8900 8336,68 28 196 4400 4286.54 26.5 164 9008 8432.59 26.75 192.5 4500 4376.03 26.5 164 9100 8514.84 26.5 192.5 Page 20 of 21 Revision 0 March, 2013 • • Anna Platform #17 Slot Recovery Procedure Hllcor Enemy 18.0 MASP Calculations fl Maximum Anticipated Surface Pressure Calculation 12 -1/4" Hole Section Anna 17 RD Cook Inlet, Alaska MD TVD Planned Top: 3522 3475 Planned TD: 10700 10237 Anticipated Formations and Pressures: Formation TVD Est Pressure Oil /Gas/Wel PPG Grad GP -C1 8,159 4000 Wet 9.4 0.490 C-4 8,544 2200 Gas 5.0 0.257 C -5A 8,659 1800 Gas 4.0 0.208 C -SB 8,729 1800 Gas 4.0 0.206 C7AT 9,039 2200 Gas 4.7 0.243 C7CT 9,109 2200 Gas 4.6 0.242 C7DT 9,178 2200 Gas 4.6 0.240 C-8A 9,278 2200 Gas 4.6 0.237 C -88 9,359 2200 Gas 4.5 0.235 C-8C 9,413 2200 Gas 4.5 0.234 C -9A 9,689 2200 Gas 4.4 0.227 C -9C 9,751 _ 4200 Wet 8.3 0.431 Offset Well Mud Densities Well Max MW Top (TVD) lottom (TVD Date Anna 17 9 ppg 3,500 10,020 1977 GP 13 -11 RD 9.8 ppg 3,975 10,100 1992 GP if 50 9.4 ppg 3,880 9,851 1992 Anna 03 RD 10.5 ppg 7,755 10,219 1994 Assumptions: 1. Wet formation fluid gradient estimated at 8.5 ppg (0.442 psi /ft) 2. Fracture gradient at 3,522' MD / 3475' TVD is estimated at 0.85 psi / ft based on field test data. Fracture Pressure at 13 -3/8" shoe considering a full column of gas from shoe to surface: 3475 (ft) x 0.85(psi/ft)* 2953 psi 2953(psi) - [0.1(psi /ft) *3475(ft))= I 2606 psi MASP from pore pressure (weilbore evacuated to gas from C4) 8544(ft) x 0.257(psi/ft)= 2195 • si 2195(psi) - [0.1(psi /ft) "8544(ft)) = MASP from pore pressure (wellbore evacuated to water from GP -C1): 8159(ft) x 0.490(psi /ft)= 4000 psi 4000(psi) - [0.442(psi/ft)`8159(ft)) =1 394 psi I Summary: 1. MASP while drilling 12 -1/4" production hole Is governed by 51BHP - gas gradient to surface from the C4 sand (1341 psi). Page 21 of 21 Revision 0 March, 2013 • • Page 1 of I Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. • • Page 1 of 1 Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp @chevron.com] Sent: Friday, October 14, 2011 7:31 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Cole, David A; Martin, J. Hal; Lambert, Steve A; Ayer, Phil M; Ross, Gary D; Quick, Mike [ASRC]; Hallett, Trudi R. Subject: 2011 Third Quarter's LTSI Well Monitoring Report Attachments: Master Well List TIO Report 2011 10 01.xis Hi Tom & Jim, Here is the third quarter's report for the LTSI wells utilizing pressure monitoring in lieu of an MIT to determine any mechanical integrity problems. The wells G -29RD, G -27, G -22 & G -5RD have been moved to this LTSI report as their downhole problems (like parted tubing) do not allow a temp survey to be run to the proper depth to confirm water entry into the perfs. As a result, they are all shut -in and will remain so for now. 1"1'1,-0"1 The An -17, An -29, Ba -16 & GPP 33 -14RD wells showed increases in the 13 3/8" annulus, but they all have leveled off lately. Ba -17, after an MIT, was used in August to disposed of some fluids collected during the well kill operations on Baker. It may be used again in October for fluids collected during a well abandonment operation. I have left this well on the LTSI well list because after this usage, the well will revert to being shut -in for the foreseeable future. All the pressures seen during the usage in August looked appropriate and the well appears to have maintained its • mechanical integrity throughout the disposal operations. The general pattern of stable or slowly rising pressure trends continued this month for the Baker & Dillon wells on this list with the only other pressure anomaly related to the seasonal trend in pressures apparent in Ba -15RD. The well kill operations performed on the Dillon platform in August show up very clearly on the plots. Other than the noted issues, there doesn't appear to be any wells that show indications of any well integrity problems. Larry 10/14/2011 Plot Pressure vs Time - Well An -17 • 400. _, , „..„,..,_... , 200 180 350 . "'..9 5/8" 13 3/8" 160 300 Tubing _ _ Vol 17-42 140 250 - 120 i .r '41 200 — ..._ -.. - ...___ .__. -- -- -- — — - - 14 a. 80 150 60 100 40 5 - 20 0 rk �k . - 0 c, 03 O O N N O o co M h N 4 0 O O 0 co O Date 13 3/8" 20" TubinriIMPIPM TIO Report 10/01/11 286 175 0 09/30/11 284 175 0 Data Sheet 09/29/11 283 175 0 09/28/11 280 175 0 09/27/11 283 175 0 An -17 09/26/11 280 175 0 09/25/11 280 175 0 0 09/24/11 283 175 0 0 INJECTION 09/23/11 286 175 0 0 09/22/11 286 175 0 0 09/21/11 289 175 0 o Permit # 1770750 09/20/11 286 175 0 0 09/19/11 280 175 0 0 09/18/11 280 175 0 Suiiury # 3G1-3G5 09/17/11 280 175 0 09/16/11 278 175 0 09/15/11 283 175 0 API # 50- 733 - 20311 -00 09/14/11 278 175 0 09/13/11 284 175 0 09/12/11 280 175 0 04/01/2011 to 10/01/2011 09/11/11 277 174 0 0 09/10/11 278 176 0 0 09/09/11 277 175 0 0 09/08/11 278 175 0 0 09/07/11 280 174 0 0 09/06/11 280 175 0 0 09/05/11 278 175 0 0 09/04/11 267 175 0 0 09/03/11 273 175 0 0 09/02/11 261 175 0 0 09/01/11 258 175 0 0 08/31/11 295 210 0 0 08/30/11 302 215 0 0 08/29/11 302 215 0 0 08/28/11 292 210 0 0 08/27/11 295 210 0 0 10/14/2011 8:52 AM - TIO Reports 7e.xls J J Dolan Master Well List TIO Report 2011 10 01.xIs An -17 2011 First Quarter's LTSI Well Mi ring Report • Page 1 of 1 Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp @chevron.com] Sent: Thursday, April 14, 2011 7:20 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Cole, David A; Martin, J. Hal; Lambert, Steve A; Ayer, Phil M; Ross, Gary D; Quick, Mike [ASRC] Subject: 2011 First Quarter's LTSI Well Monitoring Report t`A'"\-`10S Attachments: Master Well List TIO Report 2011 03 31.xls Hi Tom & Jim, Here is the first quarter's report for the LTSI wells utilizing pressure monitoring in lieu of an MIT to determine any mechanical integrity problems. Drilling did some diagnostic pressure bleed downs on the GPP 33 -14RD well in February looking for any integrity concerns. We are monitoring the pressures and there does appear to be some outside pressure coming into the 13 3/8 ", but otherwise no communication between strings is indicated. The An -17 well is still behaving oddly. The 9 5/8" has settled down and doesn't seem to be tracking the 13 3/8 ", but now the 20" is increasing. As we watch the pressures, we'll see where they stabilize and see what that tells us. There are some interesting pressure movements with this well, but the pressures aren't high, just moving more than they have in the past. The Baker and Dillon wells have remained fairly stable since drilling completed the bleed downs and well kill operations last year. The recorded pressures for most all the wells remain fairly stable. Other than the noted issues, there doesn't appear to be any wells that show indications of any well integrity problems. Larry «Master Well List TIO Report 2011 03 31.xis» tri MINED APR 1 4 20 `r 4/14/2011 • • Plot Pressure & Rate vs Time - Well An -17 400 �r,_, ��.µw..� �_.... , ,. ...., 350 300 """""9 5/8" 13 3/8" 250 • 20 • Tubing E 3 rA 200 W a` V 150 _ — - - _ __ _ - - - -- _ . 100 / 50 — _._. 0 . 0 0 0 • 0 _ _ N N N N N N co N O> O ,- N M p O 0 O Date t 13 3/8" 20" " TIO Report 03/31/11 200 185 ,,,; 03/30/11 203 180 Data Sheet 03/29/11 200 175 03/28/11 197 170 03/27/11 197 175 An -17 03/26/11 195 185 03/25/11 194 182 03/24/11 192 175 SHUT IN 03/23/11 189 175 03/22/11 188 175 03/21/11 188 175 >.• Permit # 1770750 03/20/11 184 175 0 03/19/11 184 171 0 03/18/11 183 170 0 Sundry # 301 -365 03/17/11 0 184 167 0 03/16/11 0 183 165 0 03/15/11 10 188 167 0 API # 50- 733 - 20311 -00 03/14/11 0 186 160 0 03/13/11 20 182 160 0 03/12/11 20 183 155 0 09/29/2010 to 03/31/2011 03/11 /11 20 180 150 0 03/10/11 20 184 150 0 03/09/11 20 186 150 0 03/08/11 '? 20 184 145 0 03/07/11 >! 20 180 140 0 03/06/11 20 178 135 0 03/05/11 , 21 178 130 0 03/04/11 tt': 25 178 130 0 03/03/11 _ 25 172 125 0 03/02/11 25 170 120 0 03/01/11 ` 30 183 115 0 02/28/11 30 186 110 0 i 02/27/11 °' 40 190 100 0 02/26/11 60 190 95 0 02/24/11 190 160 0 02/23/11 '..i la 190 160 0 4/14/2011 9:36 AM - TIO Reports 7e.xls J J Dolan Master Well List TIO Report 2011 03 31 (2).xls An -17 Page 1 of 1 Maunder, Thomas E (DOA) From: Bonnett, Nigel (Nigel.Bonnett) [Nigel.Bonnett@chevron.com] Sent: Thursday, February 19, 2009 8:58 AM To: Maunder, Thomas E (DOA) Cc: Kanyer, Christopher V; Tyler, Steve L; Rose, Jim [Contractor] Subject: RE: An-17 (177-075) and G-14ARD (191-099) Morning Tom, Anna-17 was a coil tubing intervention, originally planned as a precursor to performing a well redrill operation after wells Anna-24 and Anna-32RD. However, with further analysis, the required redrill workscope resulted in marginal economics. So no operations were performed on Anna-17. G-14ARD perforating operation was cancelled due to lack of Partner support. In future, where we have cancellation of planned work which has been permitted, we will include a brief explanation as requested. Rgds, Nigel From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, February 18, 2009 3:57 PM To: Rose, Jim [Contractor] Subject: An-17 (177-075) and G-14ARD (191-099) Jim, I am reviewing the 404s submitted to closeout the sundries for work on these wells. Could you provide a little further information for the files? Thanks in advance. If future work is cancelled, please include a short explanation with the 404. Thanks in advance. Tom Maunder, PE AOGCC 2/19/2009 ~E~~~ STATE OF ALASKA ALA~OIL AND GAS CONSERVATION COMM~ REPORT OF SUNDRY WELL OPEE~pTI ~S~ ~ 7.0(lg ~t al ska tai & rae c~.,n ~_ 1. Operations Abandon Repair Well Plug Perforations Stimulate SIOgCancellation of CT Af?Ghpr Performed: Alter Casing ^ Pull Tubing[] Perforate New Pool ^ Waiver^ Time nsion ^ Cleanout Change Approved Program Q • Operat. Shutdown[] Perforate ^ Re-enter Suspended Well ^ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name:. Development ^ Exploratory^ 177-075 . 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic ^ ~ Service ~ 6. API Number: 50-733-20311-00 ` 7. KB Elevation (ft): 9. Well Name and Number: 105' AMSL Granite Pt. State 18742 17 (AN-17) 8. Property Designation: 10. Field/Pool(s): ADL0018742 [Anna Platform] Granite Point Field /Middle Kenai Oil Pool 11. Present Well Condition Summary: Total Depth measured 10,674 feet Plugs (measured) N/A true vertical 9,972 feet Junk (measured) N/A ) ~~~~''~~yypp pp~~~'~^^++~~ + (~ v ~~i±ti:~~CO~' ~i C' j~ Vii. ~.lS (,~~}f,Y ~~'~C . Effective Depth measured 10,400 feet true vertical 9,704 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 610' 20" 610' 609' 1,900 psi 480 psi Surface 3,514' 13-3/8" 3,514' 3,458' 2,730 psi 1,130 psi Intermediate Production 10,633' 9-5/8" 10,633' 9,960' 6,820 psi 4,230 psi Liner Perforation depth: Measured depth: 9,660'-10,334' True Vertical depth: 9,039'-9,645' Tubing: (size, grade, and measured depth) 3-1/2" 9.2# L-80 9,612' Packers and SSSV (type and measured depth) Baker Model D / N/A 9,591' / N/A 12. Stimulation or cement squeeze summary: N/A 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: Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory^ Development ^ Service Q Daily Report of Well Operations N/A 16. Well Status after work: Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ~ 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: 308-013 Contact Jim Rose 263-7637 Printed Name Timothy C. Brandenburg Title Drilling Manager ~ ~ Signature Phone 276-7600 Date 2/10/2009 ~1 Form 10-404 Revised 04/2006 Submit Original Only ~/~~ r Chevron ~ RKB = 105' TBG Hgr = x' Anna Platform Well No. 17 Actual Completion 12/31/83 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 30" x # x-55 - 19.124" Surface x' 20" 91.5 # X-52 - 19.124" Surface 610' 13-3/8" 54.5, 61, K-55 & L-80 Buttress 12.347" Surface 3,514' 68, 72# 9-5/8" 40, 43.5, S-95 Buttress 8.681" Surface 10,663' 47# Tubing 3-1/2" 9.2# L-80 SCBT 2.992" 0' 9,612' JEWELRY DETAIL NO. Depth ID OD Item 34' Tubing Hanger, Cameron, 3-1/2" x 10" 1 35' - - 3-1/2" 8RD x 3-1/2" Butt XO 2 9,591' - - Baker F-1 Pkr 4.750 SB, w/ Seal Assembly, 1/4/84 3 9,612' - - Mule Shoe PFRFnRATIt7N HISTt7RY Fish/Fill/Plugs NO. Death (Toa) Length Item A 10,260' 140' Tag Fill (Tagged 12/31/83) Interval Accum. Date Zone Top Btm Amt spf Comments '/14/1978 C-5 9,660' 9,725' 65' 2' Reperf - 3-1 /8" Casing 2/27/1978 C-5 9,670' 9,725' 55' 4' Reperf- 2-1 /8" Slim Kone 2/27/1978 C-5 9,758' 9,832' 74' 4' Reperf- 2-1 /8" Slim Kone /25/1978 C-5 9,880' 9,882' 2' 4' Reperf- 3-1 /8" Casing /17/1978 C-5 9,883' 9,885' 2' 3' Reperf- 3-1 /8" Casing 2/27/1978 C-7 10,114' 10,124' 10' 4' Reperf- 2-1 /8" Slim Kone 2/27/1978 C-7 10,134' 10,144' 10' 4' Reperf- 2-1 /8" Slim Kone '/14/1978 C-7 10,212' 10,272' 60' 2' Reperf- 3-1 /8" Casing '/14/1978 C-7 10,318' 10,334' 16' 2' Reperf- 3-1/8" Casing TD = 10,674' MD, 9,972' TVD PBTD = 10,400' MD = 9,704' TVD REVISED: 1/14/08 JAR Max angle = 29.5° @ 8,600' O:\DRILLING\Anna-17.doc ~~~©i~ SARAH PAL/N, GOVERNOR ALASSA OII, A1~TD (~5 333 W. 7th AVENUE, SUITE 100 C01~5ERQATI0I~T COMDII5SIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy C. Brandenburg Drilling Manager Union Oil Company of California PO Box 196247 Anchorage, AK 99519 Re: Granite Point Field, Middle Kenai Oil Pool, Granite Pt. State 18742 #17 1~ JAN ~ ~ 2008 Sundry Number: 308-013 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~2day of January, 2008 Encl. Chevron January 14, 2008 Timothy C Brandenburg Drilling Manager Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Re: Anna -17, PTD 177-075, Granite Point Field Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com e 1L.~,r~' V ~i.1 JA N Y 5 2008 ~hska (lil t~ Gas Cons. Commission Anchorage ~ JAN ~ `~' 2008 Dear Commissioner, _. Attached for your review and approval is form 10-403, Application'for Standry Approval, for planned work on the above referenced well. / } ~~3~r~//fir + ~ /°iG-<'~' The. Anna 17 (An-17) is a shut in injector that is a candidate for n Union Oil Company of California intends to perform a coiled tubing cleanout to determine the condition of the wellbore and facilitate further evaluation as a si ardk candidate. Please review and .approve the Application for Sundry Approval at the first convenient opportunity. We would like to start operations. on January 21St, 2008. Please contact Jim Rose at 907-263-7637 if you have any questions. Sincerely, ~. ... Cam'' ••- Timothy C. Brandenburg ~-~~` Drilling Manager TCB: sk Attachments: Form 10-403 in duplicate Summary of Planned Operations Current Well Sketch "". ORIGINAL Union Oil Company of California / A Chevron Company Page i of i C~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM~ION APPLICATION FOR SUNDRY APPROVALS ~~t~ ~n aar. ~S pan RE~~IV~l~ JAN 1 5 208 1. Type of Request: Abandon^ Suspend ^ Operational shutdown ^ Pertorate ^ aroer ~~ Alter casing^ Repair well Q ' Plug Pertorations ^ Stimulate ^ Time Extension rlcharage Change approved program^ Pull Tubing ^ Pertorate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development ^ Exploratory ^ 177-075 ` 3. Address: Stratigraphic ^ Service ^ . 6. API Number: PO Box 196247, Anchorage AK, 99519 50-733-20311-00 ` 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: 7 ~ ~ property line where ownership or landownership changes: /~ yZ r~°Gt~~c- ~~ ~T't,t ~ `~ Spacing Exception Required? Yes ^ No 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): t~~.'j ~~. ~ ~ Granite Point 18742 105' AMSL~ ~ Granite Point Field, Middle Kenai ,.~L 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10674' - 9972' ~ 10400' 9704' na na Casing Length Size MD TVD Burst Collapse Structural Conductor 610 20 610 609 1900 480 Surtace 3514 13 3/8 3514 3458 various various Intermediate Production 10663 9 5/8 10663 9960 various various Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9660-10334 9039-9645 3.5" L-80 9612 Packers and SSSV Type: Packers and SSSV MD (ft): Baker Mod D, SSSV na 9591 / na 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ ' 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 21-Jan-08 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: .Date: WAG ^ GINJ ^ WINJ ^~ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jim Rose, 907-263-7637 Printed Name ~~ ~, ~ Title y-~ Signature Phone - Date COMMISSION USE ONLY ~~, 1n~y b~ C3~ cy,\~~ ~a CE Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~8r ~ (~ Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ Other: ~d~ ~g~ \~~~ ~~}~-- QS p\G'n'~~ Subsequent Form Required: l~('1 ~` ~~ ~~~~ ~ 6 2~()~ vv APPROVED BY Approved b : MISSIONER THE COMMISSION Date: ~,~~d y I Form 10-403 Revised 06/2006 ~ ~~ ~~~~ ~ ~ A ~_ t~~~~ ..~~~ /~ %~ °~v Submit in Dup~6~~~ ~ i Chevron --- Anna Platform Anna 17 Basic CT Clean Out Procedure A-17 Summary of Planned Operations 1. MIRU CTU 2. NU BOPs and test 250/3000 psi per AOGCC regulations. 3. MU CT motor BHA 4. RIH and clean out scale to EOT @ 9612'. Circulate clean. 5. Continue washing in the hole to 9800'. 6. POOH. 7. RDMO CTU. 1/14/2008 Page 1 of 1 Anna Platform `~ Chevron Well No, 17 Actual Completion 12/31/83 RKB = 105' TBG Hgr = x' CASING AND TUBING DETAIL SIZE WT CRADE CONN ID TOP BTM. 30" x # x-55 - 19.124" Surface x' 20" 91.5 # X-52 - 19.124" Surface 610' 13-3/8" 54.5, 61, K-55 & L-80 Buttress 12.347" Surface 3,514' 68, 72# 9-5/8" 40, 43.5, 5-95 Buttress 8.681" Surface 10,663' 47# Tubing 3-1/2" 9.2# L-80 SCBT 2.992" 0' 9,612' JEWELRY DETAIL O. Depth ID OD Item 34' - - Tubing Hanger, Cameron, 3-1/2" x 10" 1 35' - - 3-1/2" 8RD x 3-1/2" Butt XO 2 9,591' - - Baker F-1 Pkr 4.750 SB, w/ Seal Assembly, 1/4/84 3 9,612' - - Mule Shoe Fish/Fill/Plugs NO. De th (Top) Length Item A 10,260' 140' Tag Fill (Tagged 12/31/83) PFRFl1RATi(1N i-iICTnRV Interval Accum. Date Zone ~ Top Btm Amt spf Comments '/14/1978 C-5 9,660' 9,725' 65' 2' Reperf- 3-1 /8" Casing 2/27/1978 C-5 9,670' 9,725' 55' 4' Reperf - 2-1 /8" Slim Kone 2/27/1978 C-5 9,758' 9,832' 74' 4' Reperf- 2-1 /8" Slim Kone 1/25/1978 C-5 9,880' 9,882' 2' 4' Reperf- 3-1 /8" Casing 1/17/1978 C-5 9,883' 9,885' 2' 3' Reperf- 3-1/8" Casing 2/27/1978 C-7 10,114' 10,124' 10' 4' Reperf - 2-1 /8" Slim Kone 2/27/1978 C-7 10,134' 10,144' 10' 4' Reperf- 2-1 /8" Slim Kone x/14/1978 C-7 10,212' 10,272' 60' 2' Reperf - 3-1/8" Casing x/14/1978 C-7 10,318' 10,334' 16' 2' Reperf- 3-1 /8" Casing TD = 10,674' MD, 9,972' TVD PBTD = 10,400' MD = 9,704' TVD REVISED: 1/14/08 JAR Max angle = 29.5° @ 8,600' O:~DRILLING~Anna-17.doc Unocal Corporation 909 West 94 Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 UNOCAL ) December 11, 2001 Tom Maunder State of Alaska Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 Re: Modified MIT on Anna 17 Shut-in Injection well Dear Tom: A consecutive, seven (7) day pressure surveillance was finished on the Anna 17 shut-in injector on 12/15/01. The tubing, production casing and outer casing pressures were monitored and recorded for three (3) consecutive days. The production casing pressure was altered by 200.psi. Pressures were then monitored and recorded for an additional four (4) consecutive days. See attached data sheet and well schematic. This well has experienced tbg/casing communication under high pressure conditions, but it is clear from recent pressure surveillance and testing that under the current low pressure (shut-in) cor)dition the tbg/casing are not in communication. The plan is to leave this well shut-ir{due to its low value as an injector. Therefore we ask that you approve the shut-in MIT. We have attached a 10-403 for your approval. Sincerely, Christopher A. Ruff Senior Reservoir Engineer Cook Inlet Waterflood Management RECEIVED DEC 3 1 7.001 0il & Gas Cons. Comrnissio[~ A~c~or~e Aogcc AN-17 SI MIT 12-2001.doc JJD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATIONCOMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casin~: Repair well Plugging: Time extension Stimulate: Change approved prograrr Pull tubing: Variance: Perforate: Other: Shut-In MIT 2. Name of Operate 5. Type of well 6. Datum elevation (DF or KB Union Oil Company of California (Unocal', Development 105' KB ABOVE MSL feel 3. Address Exploratory 7. Unit or Property nam( Stratigraphic: PO BOX 190247 ANC, AK. 9951! Service: ' X Granite Point 18742 4. Location of well at surfac; Leg 2, Cond. 6, Anna Platform 8. Well number 794' FNL, 603' FEL, Sec. 12-T10N-R12W-SI~ 17 At top of productive interv; 9. Permit numbe~ 77-75 At effective deptl' 10. APl number 50-733-20311-00 At total deptl' 11. Field/Poe 1314' FSL, 426' FEL, Sec. 12-T10N-R12W-SIV Granite Point Field~ Middle Kenai Sands 12. Present well condition summar Total depth: measu red 10674' feel Plugs (measu red', None true vertica 9972' feel Effective depth: measu red 10400' feel Junk (measu red', None true vertica 9704' feel casing Length Size Cementec Measured deptl' True vertical deptl' Structural Conductor 610' 20" 763 Sx 610' Surface 3514' 13-3/8" 2354 Sx 3514' Intermediate Production 10663' 9-5/8" 625 Sx 10663' Liner Perfo ration depth measu red (See Attached Wellbore Schematic', true vertica Tubing (size, grade, and measured deptl' 3.5" Buttress 9.3# N-80 to 9590 Packers and SSSV (type and measured deptl' Baker "F-1" Paker at 9591 13. AttachementE Description summary of proposal X Detailed operations prograrr BOP sketch: . . 14. Estimated date for commencing operatic 15. Status of well classification as 16. If proposal well verbally approve( Oil: Gas: Suspended: Name of approver Date approved Service X 17. I herebycertify that/th~ ~correct to the best of my knowled.( Chr?/~ Signed: Title: Senior Reservoir En~inee Date: 12/20/2001 ---- -/~ v FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval No. Plug integrity '~ BOP Test Location cleara2~-~. ~"I~' Mechanical Integrity Test o~ Subsequent form required 10- \ Approved by order of the Commissioner Original Signed By Commissioner Date dl dll · Ir· CammyOe ' C ECEIVED DEC 3 1 ZOO1 AlaskaOil & Gas Cons. Commissi°n Anchorage Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Spud Date ~d:murfao~ Loooffom I LeO 2. Slot 8, Oranfb Point Platform Anna 71t¢* ~ 803' 1rTL, SEC. 12. T10N, R12W, 12/0e/77 TO - 1:314' FSL, 426' ~ SE(~. 1:2, TION, R12W, S.M. 105* 10,674' 1M): Ia,400 I'VO 0.7O4* 20% 01,4l Cig .et et el O* llth 783 1.. oeme.~ t3 3/B**, 54,0, 8t, 88, 72dj CoO est at 3514' Mth 2334 o~, oomant ! M', 47, 43,5 end 40/rog #t at 10.803 ft GRANITE POINT ADL 18742 WELL NO. 17 MIDDLE KENN SANDS PLATFORM ANNA 1. Cameran 10" NOM Single Donut Hanger 2. 3 1/2e 8RO and 3 t/2' Buttrsoo XO 3. 3 I/2' lbbrng wtth AO Collars 4, 3 I/2" Buttroom pup wtth AB tailor 5. Locator 8, ~eol Alllmbly 3" ID 7. Idui#hoe 34* 35' 0586* 0501' 0811' 0812' 20% ti.4/ CSA 810' 13 3/B", S4.S, 81 Per~orotlofle C"S 0880-0725' 0758-0832' C-7 10,114-10,124' 10,134-10,144' 10.212-I 0.27:2' I01~18-10,334' 2t8 BC~, e ~ 114 IdCFD: 00~ ~23 1220 BBPD · ~ pd (1~0~4) NMla 351 4-10.052' ~ to 10,846, G~ CBt.. COt. e 10,400. nl· lO.2Oo' (12/31/83) PUT1) 1040O' 10 10874' 10114* 10334* ,~~~b 0 ~/e-, 47, 43.a 40/csA 10883' 32.0- 93.0' 13.3/5" OD 72.00t/It N-80 SORF CSG 32,0- 186.0' 9,625" OD 47,~/fl S-95 PROD CSG ,~.0- 610.0' 20"00 91,~/fl: §XL-52 ~ @.0- ~;I0.0' ~1~ 9t0 - 14.99.0' 13,~75" OD 54.~/fl K-55 SU~ CSG 1499,0 - 2~,73.0' 11375" OD 61.~/fl K-55 SU~ 186.0 - 2370.0' 9,,625" OD 40.OOt/fl N-80 PRO0 CS[; 2~73.0 - ,t1,:]0.0' 1~,~75" OD 68.~/ft K-55 SURF CSC 3130.0- ~14.0' 13.~" OD 72,~/~ N-80 SI~ C~ ~t).0 - ~14,0' ~0[ 2~]70.0 - 5,:148.0' 9.625" OD ~.OOt/t't S-95 PROD CSI; AN 17-2 Crani[e Point Field APl 50-733-21)311-00 ,]4,0 - 35.0 - '~', ADL 1~742 Heed FlnqDepth 34.00 Ft. Mox. Dev. ~,t Perfs. 24 Deg. ,]5,0' t~1~ ~I~N ~ Honger ~5.~' CROS~ ~ I/~," ~,D~ 31/2" B]C. t~ E~: 105' PBTD: 10400' ~: 1~74' ~ter Injection Well Lost W/O 1/5/84 Spud On 12/6/77 AN'NA PlatfO~ Leg 2, Conductor 6 lyo,e~ Sonds AN 17-2 G~'<~niJe Point Field APl 50-73,~-20311-00 ~ ADL 18742 Tbg He<~d FlngDep[h ~4.00 Ft. I~ax. Der. l[ Perfs. 24 Deg. ~.0 - ~2.1r 9.625" OD 4150t/ft S-g5 PROB (::St; 9591.0 - 96II.0' PACKER Roker F-I Pkr. 9~.0 - 9565.0' SQUEEZE PERFS C-5, Sqz'd, 2', ~F, 12/~/78 96~,0 - 96~,0' ~UEE7E PERf'$ C-5, Sqz'd, 4', ~PF, W~er Injecb'on Spud On 12/6/77 KB ELEV: 105' PBI'D: 10~' ,,q..O-9590.0' ~.~" O0 9.~/'ft N-80 IBC 9591.0- 9611.0' ~ 9590.0 - 9591.0' L~TOR JOIN]' 9670.0-9725.0' PERF'S C-§, Ini, ~', 4HPF, 2 {/~" Slim Kone Cun, I2/27/78 9660.0- 9725.0' PERfS C-5, Inj, F~', 2HPF, ;~ I/B" Cosin9 Gun, 7/14/7~ g~.(}- 9/25,(/PER6 ¢-5, Ini, 6', lttPf', ~ 1/8" Casing ~u,, f/21/18 9611.0 - 96129 MULESHO[ ANnA Platfor~n~ Leg 2, C~udor 6 Tyonek Sends AN 17-2 Groni[e Pain[ Field AP! 50-733-20511-00 ~ ADL 18742 Tbg Head FIng I~pth 34.00 Ft, Id(Ix. Dev. ~,t Perfs. 24 Deg. 9~,0 - ~)~8.0' S~UED' PF..RFS C-5, Sqz'd, ¢, 41tPF, 12/~0/~ 9701.0 - 9Y03.0' STG(X)iI~ 098.0 - 10100.0' ~UEEZE P[.I~ C-7, 4HPF, 2Il Sqz'd 12/17/78 14.0- 10124.0' ~JE~E P~S C-7, 5tiPF, 10', Sqz'd 12/17,/78 ~4.0-t01~.0' S~JEEZE P~S C-7, ~PF, 10', Sqz'd, 12/17/78 10247.0- 10280.0' FILL 3/15/8g l~ed All lo o.o- o oo.o' F LL ro lO~.O-1067~.0' C~EN1 PLUG 1/20/78 W<~ter Injection WeB Last W/O ]I5184 Spud On 12/6/77 'i:':!'i:':i I(B EIB: 105' PBI'D: 10~' Tll' Ii1~74,' 9660.0-97259 PERF'S C-5, Inj, 65', 2HPf', 3 I/8" Cosing Cun, 7/14/l$ 9660.0-9725.0' PERFS C-5, Inj, 65', ,:IHPF, :~I/~ Cos~ Gun, 1/27/7'8 9670.0-9725.0' PE~ C-5, Inj, 5~', 41.1~, 21/8" Slim Kone Cum 12/27/78 9758.0-9~2.0' PERFS C-5, Inj, 74', ~P[, 21/8" ~ Kooe OJn, 12/27/78 9758.0-9~2.0' PI]iFS C-5, lnj,/4', 3HPf', 31/8" Cosing Gun, 1/27/1~ 97,58.0- 9~2.0' PI~FS C-§, Inj, 74', 2~, ~ I/8" Cdn9 Gun, 7/14/78 9~.0-9882.0' PELFS C-5, Inj, 2', ~F, 1,/25/78 g~.O- ~.0' PERES C-5, I,j, 2', 31-1PF, $1/8" Casing Curt, 1/17/78 10114.0- 101~4.0' PERFS C-7, Inj, 10', 21{PF', ,,11/8" Casing Gun, 7/14/7§ ~o11~..o - lm24.o' ~ c-7, Ini, lO', ~PF, :~ 1/~" Co~i~ ~,, 10114.0- 10124..0' PE]]F$ C-7, ki, 10', 4HPF, 21/8" Slim K~ Curt, 12/27,/78 lol:~.o- lorn.o' Pm c-7, ~nj, 1~', ~, 21/~" Sim ~ <;,n, 12/27p~ ~omO- ~0~'~.01 PELFS C-7, ~nj, 10', 2H~, ~ 1/~" C~,O C~n, 7/1,~/78 lOm. O - 101~.0' Pm C-7, Ini, 10', ~F~, 3 1/8" Co~ir~ ~r~ 1/27/7~ 10212.0-10272.0' P~F'S C-7, Inj, rg, 2HPF,,11/8" Cesin9 Cun, 7/14/78 10212.0-10272.0' PERFS C-7, Inj, 60', 3~, 3 1/8" ¢osin9 Curt, 1/27/78 1031B,0 - 10t,,z4..~ PERF$ C-7, Inj, 16', ,,zI. IPF, 3 I/8" Cosing Gun, 1/27/78 10,]18,0-103~.0' PBtFS C-7, lnj, 16', 2HPF, 3 l/fi" Casing Curt, 7/14/71] AN-17 2001 Shut-in MIT Date 12/27/01 12/26/01 12/25/01 12/24/01 12/21/01 12/20/01 12/19/01 12/18/01 · 12/17/01 12/16/01 12/15/01 12/14/01 12/13/01 12/12/01 12/11/01 12/10/01 Tbg Length Volume Press (hours) (bpd) (psi) 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Csg Press (psi) 0 60 0 6O 0 6O 0 60 0 450 0 405 0 405 0 300 0 300 0 235 0 50 0 50 0 50 0 50 0 50 0 50 Outer Csg Press (psi) Comments 230 230 230 225 Bled off Casing pressure 300 305 300 250 286 263 Pressured up Csg for SI MIT 266 290 261 267 266 261 12/28/01 1:24 PM SI MIT Pressure Monitoring 12-2001 .xls Waterflood Injector Well Status AN-17 - SI MIT Pressure Monitoring 2~9~01 12/11/01 12/13/01 12/15/01 12/17/01 12/19/01 12/21/01 12/23/01 12/25/01 12/27/01 12~29~01 Unocal ~Anna 260 Ca14ar St. Kenai, AK gg611 December 23, 1998 81air Wonzell AOAGA Dear$ir: TI~ is to inform you of a possible communication problem ~ the tubing and casing on our well ~?~7 water injector here on platform ANNA. We shut the well in the evening of December 22, We are currently arranging to have the wellhead tested for leaks before farming tests on the tubing. We will keep you infom~ed as t~ our progress, CoUld yoU please fax us a written mnfirmation tiler you have received this notlce? Our Fax number is (907) 776-6625. We w~JId like to keep a copy in our records, If you have any father quesllans please ~a~ (~o?) Dan R, Moultrie Platform Anna (Lead C -iVED DEC 2 3 i998 Ala~O~ & Gas Cons. Comn~axl DF_rS. :"4. :,'l~kl'! ~: ~:'"HF! ~v. ~.~.~ ..... Procednre for Platform 1. Record daily tubing, casing, and outer casing pressures for a consecutive three day pedod. 2. Increase casing pressure by 200 psi, Continue recording daily tubing, casing, and outer casing pressures for an additional consecutive four day period. ' i~ll P,rq~ll(Ire ,, ,'"' ...... ' I ,i ' ] IlJ ~,,III i ,' e Tupid 'Pm.nat!__ ./ " '. , '- ', , ,~ ,.t;I ' ,.., ~,!1~ ~, ~ ' , '. ~ , , , -, .'. · , iI ,,, ~ .... , ~ ' ,.' ., mm --- ill m ~ , i _ ] /z-/~/ ..... ~ .... ~ .... ~_~ I I I II III I ....... ,. ii i iiii ; i' i ilil i i _ III I I I I I BI Pressures Recorded By: Poet-it' Fax Note 7671' JJl) C;~De~l~lTS ~tqd :Settinlts~lela~Laea! Smin~stTempmary Oroctdll.re 20e12001 .DOC 1%42 Spmial MIT '"' MIT ~'EST we, # /'7 I I I III II I lift I Date Time 9 518" 13-3,i8" 20" I i I I IIIl 12 "t~ * oi ~ Pm "1. ~ ~.¢b ,. !O .... fP- ~ ~ ,,, .. ~ p~ .... ~~ Z.e~ /~ ._. ~ P~ 3~ 3o5 ~. , , , ,, .. ,8,.,,,~ ~¢_~ ~0$ .... ...... ~ & ~ ~¢ ~ ..... [~ ?~.~ .................. - , - i . ,t~*. . ..... _ - mm mm ~ I m [ , m. i - . ,- ..... ,,, L. A. Darsow District Superintendent Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 February 24, 1984 File' WEN-2OO-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99501 Commi s s i on Dear Si r: Subsequent Noti ce Granite Point 18742 Well No. 17 Platform Anna, Cook Inlet, Alaska Attached in duplicate is a State of Alaska Form 10-403, Sundry Notices and Reports on Wells, subsequent to converting Granite Point 18742 Well No. 17 to water in~tion. Post-workover injection rates were 1,229 BWPD at 4,000 ps~i. l~l-e~e direct any questions concerning the project to Mike Schwein in our Anchorage office. Very truly yours, W. E. Nielsen Supervi sor-i n-Charge Attachment MTS/seh g£C£1VED F'ER 2 1984 Oil ~~ ~-'Gas Cons. Com.~is~io~ ..... u. ~e STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION CuMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ OTHER 2. Name of Operator Amoco Production Company 3. Address P. O..Box 100779, Anchorage, ^laska 99510 4. Location of Well Leg 2, Slot 6, Granite Point Platform Anna 794' FNL, 603' FEL, Sec. 12, T10N, R12W, SiM. 5. Elevation in feet (indicate KB, DF, etc.) 105' ' KB, MSL i2. 7. Permit No. 77-75 8, APl Number 5o- 733-20311-00 9. Unit or Lease Name Granite Point 18742 · ~10. Well Number 17 11. Field and Pool Granite Point Field J 6. Lease Designation and Serial No. Mi ddle Kenai Sands ... .ADL 18742 Check Appropriate-BOx To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate .[] Alter Casing [] Perforations [] Altering Casing Stimulate . [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made r-1 Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Amoco Production Company performed the following work' . . mi 5. 6. 7. 8. . 10. Rigged UP wireline and tested lubricator to 2,500 psi. Cut short string and perforated long string and rigged down. Circulated and killed well with filtered Inlet water. Set back-pressure valves, nippled down tree, nippled up BOP's and tested to 2,500 psi. Pulled back-pressure valves. Pulled tubing-and bottomhole assembly. Cleaned out to 10,280 feet and scraped to 9,640 feet. Set permanent packer at 9,590 feet. Ran in tubing. Displaced annulus with inhibited filtered Inlet water and landed tubing. Mule shoe set at 9,612 feet. Set back-pressure valves, nippled down BOP's, nippled up tree and tested to 5,600 psi. Pulled back-pressure valves. Hooked up flowlines and placed well on injection. RE£E VED 14. I hereby certify that the foregoing is true and correct to the best of rny knowledge, Sign .~ .'~~~'"~ - Title ~ Su,Pe, rvi sor-in-Ch~ r.e The space below for Commission use Conditions of Approval, ff any: By Order of Approved by COMM. ISSIONER the Commission Form 10-403 Date Submm! "intentions" mn mr~phcale Rev. 7-1-80 ;Ind "Subse~luen! Repmrls" ~n l)upl,c;l:e L. A. Darsow District Superintendent Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 October 18, 1983 File: LAD-9OO-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Granite Point 18742 Well No. 17 Platform Anna, Cook Inlet, Alaska Attached in triplicate is State of Alaska Form 10-403, Sundry Notices and Reports on Wells, notifying you of our intent to convert the subject well to injection. Well No. 17 was completed in February 1978 with an initial potential of · 218 BOPD, 6 BWPD, and 114 MCFD. Production was stable between 100-200 BOPD and 10-40 BWPD until waterflood breakthrough occurred in mid-1981. Production since then has rapidly declined to 0 BOPD and 240 BWPD. The well has been shut in. We plan to convert Well No. 17 to injection and expect to inject 500 BWPD at 5000 psi. Any questions can'be referred to Lynn Aleshire in our Anchorage office. Very truly yours, L. A. Darsow District Superintendent Attachments LMA:seh RE[E VED Alaska 0il & Gas Cons, ~Jommission Anchorage STATE OF ALASKA ALASKA UlL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator Amoco Production Company 3. Address P. 0. Box 100779, Anchorage, Alaska 99510 4. Location of Well Leg 2, Slot 6 Platform Anna 794' FNL, 603' FEL, Sec. 12, T10N, R12W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 105' KB-HSL 6. Lease Designation and Serial No. ADL 18742 7. Permit No. 77-75 8. APl Number 50- 733-20311-00 9. Unit or Lease Name Granite Point 18742 10. Well Number 17 11. Field and Pool Granite Point Field Middle Kenai Sands 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other JX-] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other [] [] [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Amoco plans to perform the following work on well No. 17 in October 1983. . . . 8. 9. 10. 11. Circulate and kill well with filtered Inlet water. Set back-pressure valves, nipple down tree, nipple up BOP's and test to 2,500 psi. Pull back-pressure valves. Rig up wireline and test lubricator to 2,500 psi. Cut short string and rig down. Pull tubing and bottomhole assembly. Clean out to PBD at 10,413 feet. Scrape to 9,650 feet. Set permanent packer at 9,575 feet. Run in tubing dry with disc assembly and surge perforations. Run plug and pressure test tubing. Displace annulus with inhibited fresh water and land tubing. Set back-pressure valves, nipple down BOP's, nipple up tree and test to 5,600 psi. Pull back-pressure valves. Hook up flowlines and place well on injection. RE E VED a'oseque~nt Work Reported[ 14. I hereby certify that th~ng is true and correct to the best of my knowledge. Signed W Title District Superintendent The space below for Commission use .Alaska Oil & Gas Cons, Commission, Anchorage Conditions of Approval, if any: ApprOved by. ORIGINAl. SIGNED BY HARRY W. KIIGLER Returned Id. ,,~,~,., By Order of COMMISSIONER theCommiss~on Form 10-403 Rev. 7-1-80 SubmJ! "lnlent~ons" m Triplicate and "Subsequent Hepo~ IS" ~n Duplicate L. A. Darsow District Superintendent February 21, 1979: File:' LAD-175-WF Mr. Hoyle H. Hamilton, Commissioner' Alaska Oil and Gas Conservation Commission 3001 POrcupine Drive' Anchorage,'Alaska 99501 Amoco Production Company Post Office Box 779 Anchorage, Alaska 99510 907 - 272-8471 Dear Mr. Hamilton: Subsequent.Report' Granite'Point'18742',Well No. 17. Platform Anna~ CoOk Inlets'Alaska. Attached'please. find.the'State-of Alaska'Form 10-403, Sundry Notices'and ~RepOrts'on.Wells in:duplicate.' iThis is a:subsequent.report of the,,water' shut-off.repair and.cement squeeze.performed'on Granite Point18742 Well No. 17. Yours .very truly, L. A. Darsow District Superintendent ' Attachment MJN:sls Anolmra.~o Form 10-403 · ~ Submit"lntentions" in Triplicate REV. 1-10.73 ~ & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELL 1.4~1 WELL i-_J OTHER ' 2. NAME OF OPERATOR Amoco Producl;ion Company 3. ADDRESS OF OPERATOR P. O. Box 779, Anchorage, ~ Alaska 4. LOCATION OF WELL 5. APl NUMERICAL CODE 50-133-20311 6. LEASE DESIGNATION AND SERIAL NO. ADL 18742 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. uNIT, FARM OR LEASE NAME Granite Point State 18742 9. WELL NO. 10. FIELD AND POOL, OR WILDCAT At su ~ace Leg 2, Slot 6, Platform Anna 794' FNL, 603' FEL, Sec, 12, T10N, R12W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, et~) 105' RKB-MSL 14. Granite Point 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec, 12, T10N, R12W, S.M. 12- PERMIT NO. 77-75 Check Appropriate Box To Indicate Nature of Notice, Re )ort, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR AClDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTER lNG CAS lNG SNOOTING OR ACIDIZlNG ABANDONMENT* (Other) cement s~ueeze, (NOTE~ Repo~ results of multiple completion on Well C~Dletlon or Recompletion Repo~ and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. The operator performed the following work betWeen'December. 11, 1978 and January 29, 1979: . 2. 3. 4. e e e 10. Displace well with filtered treated'Inlet*water. Pull production eqUipment, Clean out to PBTD, 10413.feet, Pressure test perforations 10099-10144' to .450 psi. Circulate at 2 BPM and communicate with annulus. Pressure test perforations 9883-9885' to 1000 psi and 9758-9832' to 1000 psi. Tested good. Set'drillable bridge Plug at 10176' and.cement.retainer'at 9928'. Cement squeeze perforations 10099-10144' with 200 sacks Class G cement. Circulate back out 40 sacks. Tag cement at 9757' and clean.out to'PBTD, 10413'. cement squeeze tested good. Set drillable bridge Plugs at 9744' .and 9652'. Perforate 9644-9648' at 4 JSPF with 2-1/8" Slim Kone gun. PresSure.test to 2600 psi,.held OK. .Perforate 9563-9565' at 4 JSPF and test to'2600 psi. Held OK. Reperforate Using 2-5/8" Slim Kone guns at 4 JSPF, from Sonic dated 1-17-78, the following depths: 10134-10144', 10114-10124', 9758'9832', 9670-9725'. Run dual 3-1/2" tubing string and a Kobe Type "B" bottomhole assembly. Place well on test. Production before workover: 0 BOPD, 0 MCFD, 437 BWPD, 100% BS&W production after workover, test of 1-29-79: 113 BOPD, 37 BWPD, 0 MCFD, 24.6% BS&W 16. I hereby certify that the foreg/~j}is true and correct mATE ~ebruar7 21, 1979 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, I F ANY: T IT LE DATE See Instructions On Reverse Side L. A. Darsow District Superintendent December 7, 1978 File: LAD-1128-WF Mr. Hoyle H. Hamilton, Director Division of Oil and Gas Conservation Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Amoco Production Company Post Office Box 779 Anchorage, Alaska 99510 907 - 272-8471 C. G :' Oi] I s I I_.R~v I CONFER: Dear Mr. Hamilton: Subsequent Notice and Notice of Intent Granite Point 18742 Well No. 17. Platform Anna~ Cook Inlet~ Alaska On December 1, 1978. as discussed between Mr. G. R. McGregor of this office and Mr. R. A. Douglass, verbal approval'was obtained to repair Granite Point 18742 Well No. 17. This well, since the workover to acidizeand reperforate the C-5 and C-7 zones, between July 10, 1978 and July 29, 1978.,'has produced excessive amounts of water. This highwater production and associated-calcium'carbonate scale problems'has caused a series of serious mechanical problems thathas made further production impractical. In order to eliminate this water production, a repair will be necessary, as set forth in the attached Notice of Intent, filed in triplicate, on the State of Alaska Form No. 10-403.' Also, please find attached a Subsequent Report on the acidizing and reperforating of the C-5 and C-7 zones, filed in duplicate, on the State of Alaska Form No. 10-403.' Yours very truly, 1',. A. Darsow District Superintendent Attachments MJN:sls 4nOhoral~' 6°hsu~,~tlu~ Form 10-403 REV. 1-10~73 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such propo~s.~ WELL i i OTHER BEC 7 I978 Amoco Production Company 3. ADDRESS OF OPERATOR Divisi0r) 0i ~;~J ~:,r.~:; ~;~s Cu,~ ~. 0. Sox 779, Aacho~age~ ~as~ 995~0 4. LOCATION OF WELL ~0~;or~ APl NUMERICAL CODE 50-133-20311 6. LEASE DESIGNATION AND SERIAL NO. APL 18742 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Granite Point State 18742 9. WELL NO. ~ti~7 10. FIELD AND POOL, OR WILDCAT At su ~ace Leg 2, Slot 6, Platform Anna 794' FNL, 603" FEL, Sec. 12, TiON, R12W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, et~) 105' RKB-MSL 14. Granite Point 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 12, T10N, R12W, S.M. 12. PERMIT NO. 77-75 Check Appropriate Box To Indicate Nature of Notice, Re )ort, or Other Data NOTICE OF INTENTION TO.' FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF; WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTER lNG CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. The operator performed the following work between July 10, 1978 and July 29, 1978. ® Kill well with diesel. Pull production equipment. Reperforate the following intervalsat 2 JSPF using a 3-1/8" decentralized 0 degree phased'casing gun. C-5 9660- 9725' 9758-'9832' C-7 10114-10124' 10134'10144' 10212-10272' 10318-1033~' 4. Acidize the C-7.with 8300gallons Dowell clay acid and 4800'gallon~ Dowell 12-10 Mud Acid, 5.' Acidize the C-5 with ll,700*gallons of Clay Acid and 6950*gallons 12-10 Mud Acid. 6. Ran 3-1/2" tubing and placed well back on Kobe hydraulic pump. · Production prior to this workover was 179 BOPD and 0 BW-PD. Production after the work during the month of October'was 0 BOPD and 430' BWPD. 16. I hereby certify that the fore~Ot, ng is true and correct TITLE District Superintendent DATE December 7, 1978 (This space for State office use) R.A. Douglass APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE Petrolet~n Engineer DATE Deceat~r 12, 1978 See Instructions On Reverse Side Approved -opy Returned Form 10-403 REV. 1-10~73 Submit '1 ntentions" in TripliCate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELL L..J OTHER ' 2. NAME OF OPERATOR Amoco Production Company 3. ADDRESS OF OPERATOR 5. APl NUMERICAL CODE 50-133-20311 6. LE~SE DESIGNATION AND SERIAL NO. ADL 18742 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Grant~ Point State 18742 9. WELL NO. . P. O. Bog 779, A~nhoramm: Alm.~i~m qq%l('t 4. LOCATION OF WELL At SUrface Leg 2, S16t 6, Platform Anna 794' FNL, 603' FEL, Sec. 12, T10N, R12W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 105 ' RKB-MSL 14. 17 10. FIELD AND POOL, OR WILDCAT Granite Point 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 12. TiON. R12W. S*M. 12. PERMIT NO. 77-75 Check Appropriate Box To Indicate Nature of Notice, Re )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) C eTnel't t PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF [~ REPAIRING WELL FRACTURE TREATMENTH ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE8 Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. The operator proposes to repair the well as follOWs: . 10. 11. We anticipate this workover to start on December 13, 1978. 1. Kill well with diesel. 2. Pull production equipment. 3. Pressure test perforations at '10,100-10,102' and 9880-9882' with a packer and bridge plug. Cement squeeze if required. 4. Set drillable bridge plugs at 9740' and 9650'. 5. Perforate at 9644-9648' with 4 JSPF. 6. Cement squeeze the upper C-5 interval. 7. Perforate at 9563-9565' and cement squeeze. 8. Clean out with bit and scraper and pressure test cement squeeze intervals. Resqueeze where required. Clean out to PBD (10,413'). Reperforate the C-5 and any other required zones. R ~ C ~1~ E D Run production equipment and test. ? 1 7B 16. I hereby certify that the/tb-~?going is true and correct District Superintendent TITLE DATE December 7, 1978 (This space for State office use) R.A. Douglass APPROVED BY, CONDITIONS OF APPROVAL, IF ANY: TITLE . Petroleum Engineer See Instructions On Reverse Side December 12, 1978 DATE L. A. Darsow Area Superintendent July 3, 1978' File: LAD-666-WF Mr. Hoyle Hamilton, Director Division of Oil and Gas Conservation Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Amoco Production Compan~ P.O. Box 779 Anchorage, Alaska 99510 I Dear Mr. Hamilton: Notice of Intent Granite Point 18742 Well No. 17 · Platform Anna Cook Inlet~ Alaska Attached for your approval is State of Alaska Form No. 10-403 in triplicate. We propose a workover to reperforate the C-5 and C-7 zones and treat them with an acid stimulation. Very truly yours, /?/' L. A. Darsow Area Superintendent Attachments RECEIVED RET:sls Form 10-403 REV. 1-10~73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELL!1 OTHER 2. NAME OF OPERATOR Amoco Production Company 3. ADDRESS OF OPERATOR P.O. Box 779, Anchorage, A~aska 99510 4. LOCATION OF WELL At surface 794' FNL, 603' FEL, Sec. 12, Ti~N, ~12W, Leg .2, Slot 6, Platform Anna 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 105' KB-MSL 14. Check Appropriate Box To Indicate Nature of Notice, Re [5. APl NUMERICAL CODE 50-133-20311 6. LF.~SE DESIGNATION AND SERIAL NO. APL 18742 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Granlte Point State 187/+2 9. WELL NO. 17 10. FIELD AND POOL, OR WILDCAT Granite Point 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 12, T10N, R12W, 12. PERMIT NO. 77-75 ~ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE_TREAT SHOOT ~tClDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR AClDIZlNG ABANDONMENT* (Other) (NOTE-' Report results of multiple completion on Welt Completion or Recompletlon Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all 13ertlnent details, and give pertinent dates, Including estimated date of starting any proposed work. Amoco proposes to workover the well as follows: 1. Kill well with diesel. Diwwo,,/ 2. Pull production equipment. 3- 1{eperforat:e C-5 tntez~rals 9660-9725', 9758-9832' and C-7 :Lnteg-,raZs 10114-10124', 10134-10144', 102i2-10272', 10318-10334' with 2 JSPF uslng decentralized 3-1/8" casln8 Suns down drlllplpa with 0' phasing. 4. Isolate the C-7 lnterval w/th retrievable bridge plug and packer and acldtze wlch 6950 gallons Dowel1 12-10 Mud Acld and 11260 gallons Dowel1 Clay Acld.. 5. Isolate the C-5 interval w/th retrievable brldge plug and packer and actdlze wlch 4800 gallons Dowell 12-10 Mud Acld and 7780 gallons Dowel1 Clay Acld. 6. IteCurn well to production. 16. I hereby cea[tltYurlgJ~l~t'th~'f°reg°lng isal ~[~gn~fl] ll)~true and correct ~..A. DARSOW SIGNED L. A. Darsow T~TLE Area Superintendent DATE.JUly 3~ 1978 (This space for State office use) CONDITIONS OF APPROVAL, IF ANY Petroleum Engineer See Instructions On Reverse Side DATE July 12, 1978 ,Approved ;op¥ [ietumed L. A. Darsow Area Superintendent March 20, 1978 Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 File: LAD-291-WF Mr. O. K. Gilbreth, Director Division of Oil and Gas Conservation Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Completion Report Granite Point 18742 Well No. 17 Platform Anna Attached is your Form P-7 for the completion of drilling Granite Point 18742 Well No. 17. Also attached is a copy of the chronological history and directional survey. The open hole logs have.already been forwarded to you by Schlumberger Offshore Services. Yours very truly, L. A. Dar sow Area Superintendent Attachments RET:klt l-'or :~ P---7 i : SUBMIT IN DUPLICATE* STATE OF ALASKA ',see other in- structions on OIL AND GAS CONSERVATION COMMITTEE rev~,'s~ ,iae~ 8. APZ Ntnl~C.~ COD~. 50--133--20311 WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* ' ai la. TYPE OF WELL: OIL (;AS~ -- WELL WELL J J DRY J'J Other b. TYPE OF COMPLETION: Ngw ~--] WOnK DEEP- [~ PLUG ['~ WELL OVER ~l EN BACK ~]~ DIFF.EESVR.Other 9. N&ME OF 0PZRATOR Amoco Production.. Company 3. ADDRESS OF OPERATOR P. 0. Box 779, Allchora~e. Alaska 99510 ~. LOCATION OF WEL£--(Report location c~early and in accordance with any State requirements)* At surface 794' FNL, 603' FEL, Sec. 12, TI0N, R12W, S.S. Le 2. Slot 6, Platform Anna At top prod. inter~}l relSorted below 1610' FSL, 248' FEL, Sec. 12, T10N, R12W, S.M. At total depth ~ 1314' FSL, 426' FEL, Sec.'12, T10N, R12W, S.S. 12. PI~RAilTI~O. 12--6--77 [ 1-16-78 . [ 3-6-78 [ 10~ ' KB MSL . ~ 18. TOTAL DEPTH, 1VLD & TVD[19. PLUG, B~CK MD & TVD[I[0. IF 1VUJLT1PLE COM~L., 21. INTERVALS DRILLED BY ! [ HOW MANY* ROTARY TOOLS "[ CABLE TOOLS 10,6~b'MI) 9972'TVD ! 10,400'MD 9704'TV~ 0-10674 22. PRODUCING INTERVAL(S), OF THIS COMPLETIOiN'--TOP, BOTTOM, NA1VIE (MD AND TV'D)* 1 23. WAS DIRECTIONAL I SURVEY MADE 9~'660' ~D 9021''TVD I 10~ 3~4._':. MD 9639' 'TVD Middle Kenai Sands - "C" Unit i Yes 8. LEASE DESIGNATiON A_ND SER][AL NO. ADL 18742 ?. IF IHT)lA-N, ALLO~ OR TRIBE N~d~IE 8. UNIT,FAll/VI OR LEASE NAME Granite Point State 18742 9. WELL NO. 17 10. FLEI~ A~D POOL, OR WILDCAT Granite Poill~ 11. SEC., T., R., M., (BOTTOM HOr-I~- OBJEC'rlVE) . Sec, 12, T10N, R12W, S.M. 24. TYPE ELECTRIC AND OTHER LOGS RUN , G..:BHCyC¥~i~er~- ~:'~ , HDC , TES-SP :: CASING RECORD (Report all strings set in well) CAS_I~NG SIZE WEIGHT~ LB/~. D~ ~T (~) HOLE S~E C~%~NTING RECO~ 20" 6~ 13-3 10,6' 26. LIN~,~ tLECOt~I) 281 PEP~FORATIONS OP~.~I TO PRODUC'I'ION (Interval, size and number)' 763 sacks sacks 625 sacks 27. TUBING RE COIV~D AIVI OLrI~T PULLED $CP~E1KN (MD) SIZE DEPTH SET (MD) [ PACt[ER SET (MD) 349' 9660-9725' 9758-9832' 10,114-10,124' 10,134-10,144' 10,212-10,272' 10,3i8-10,334' 3--1 /R" r~.~n~ ~,,n.~ at _3 JSPF 3O. PRODUCTION 29. . ACID, St!OT, F~/%CTURE, CIe-,IIE:NT SQUEEZE, ETC. DI~IPTI-I INT]/IRVAL (MD) AMOUNf .~dqD KIND OF MA.'I~/R.IAL USED DATE FIRST P1ZODUCTION 2'1-78 DAT~ OF TruST, JI-iOl3~S TESTEID JCHOIiE SIZE JPROD'N FOR · ! I ITES'r P~OD '__.2~-6'78 , l- 24 ! I ~' FLOW; ~BINa ~ASma P~S~ ICaL~~ O~BL. ~ss. I . . [~,~oua aa~ 4 65 I 6} ] "' > [ 218 31. VlSPOSlTION O~ g*S (80lg, ~g lot 1~I, v6nt6d; etc.) : F, ge~ and Sales ~ PI~ODUCTION METHOD (Flowh~g, gas lifL pumping--size and type of pump) KObe Hydraulic Pump MAR 2 1 ' OIL--BBL. G.a_S---1ViCF. WATEH,---BBL. J GAS-OIL R~%TIO l. 1114 I6 J 523 GA~. W~BBL. J OIL GRAVITY-~I (CO~.) ITEST WITNE88gD B~ 32. LIST OF ATTACHMENTS Chronological history, directional survey 33. I hereb~ certify that t~he fo.r~ping and attached information is complete and correct as determined from alVavallable records ~~ ~~*yqi~'--~ Area Superintendent SIGNED TITLE DATE March 20:1.9_7_8 *(See In,truction, and Spaces [or Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end :tog on all types of lands and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- merits given in clher spaces on this form and in any attach?.~er~ts Items 20, and 22:: If this well is completed for separatc prcduction from more than one interval zone (mulliple completion), so state ~n item 20, and in ite,,~ 22 show the p~cJuc~Cl interval, or ~nte~v,~ls, top(s), bottom(s) and name (s) (if any) for only the inter¥,~! ret¢orfcd i~ ite~ 30 Swl:'w'nlt a sep3rate report (pa0e) on this form, adequately identified, for each additional interval to be separately producert, show- ing the ack. Jitional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and, the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). ,, 34. SUMMAItV O1" I"¢)ltMrATION 'I'~T.'~ IN('I_.IJI)IN(; INTHIIVAL TFlX'FED. I)I~StJI{E I)A3'A ~ ~'()VEI~I~N ()F OIL GAS. 35 G~GIC MARK~ WAT~ AND MUD State "A" 6824 ' 6471' State "B" 7436' 7036' State "C" 9108 ' 8522' C-2 9332' 8723' C-3 9404' 8788' ANa I)E~t'~'~D Si:t~)WS OF OiL. GAS Oil WAq~I. ' " - 9430' 8 12~ ., C-5 9576' 8944' C-6 9850' 9195' C27 10,060' 9389' C-8 ~0,420' 9727' Chronological History December 4, 1977 December 5 December 6 December. 7 December 8 December 9 December 10-11 December 12-13 December 14-15 December 16'17 December 18 December 19 December 20 December 21-31 January 1, 1978 January 1-16 January 17-19 January 20-21 January 22 January 23-24 January 25-27 Rig operations commenced. Rig up. TD: 282'. Drilling 26" hole. TD: 625'. Dynadrill 282-312', drilling, Gyro Survey. TD: 625'. RU and run 15 jts. 20" casing, set at 610' cement with 763 sx Class G cement, and NU 20" head~ TD: 611'. NU BOP, drill 20" shoe. TD: 2048'. Drilling, Dynadrill 12-1/4" hole to 2048'. TD: 3530'. Drilling 12-1/4" hole. TD: 3530'. Open hole to 17-1/2" (2872-3100'). TD: 3530'. Run 90 jts. of 13-3/8" casing, landed at 3514', cement with 2354 sx Class G cement. TD: 3530'. NU and test BOP's. TD: 3671'. Tested casing at 1500 psi, drilling out cement, run Gyro Survey. Drilling 12-1/4" hole. TD: 3880'. Dynadrill 3671-3790' drilling. TD: 8316'. Drilling 12-1/4" hole. TD: 8479'. Drilling 12-1/4" hole. TD: 10,674'. Drilling 12-1/4" hole. TD: 10,674'. Logging. Run IES 10,652-3,514', GR-BHC- Caliper 10,656-3514', Run dipmeter to 10,648'. TD: 10,674'. Run 254 jts. 9-5/8" 47#, 43.5#, 40# S-95 Buttress casing. Cement with 625 sx Type G cement. TD: 10,674'. NU and test BOP's. TD: 10,674'. Drill out cement to 10,400', Run GR-CBL-CCL. PBD: 10,400'. Perforate the following: 9660-9.725' 9758-9832' 10,114-10,124' 10,134-10,144' 10,212-10,272' '10,318-10,334' with 3-1/8" casing guns at 3 JSPF. January 28-31 PBD 10,400'. RuD 3-1/2" tubing to 10,349' and Kobe pump and BHA. Rig released 0600 hours January 31, 1978. February 1-March 6 PBD 10,400'. Well on test. March 6 TD 10,674'. PBD 10,400'. Completed as Middle Kenai Sands producer on March 6, 1978. Surface location: 794' FNL, 603' FEL, Section 12, T10N, R12W, S.M. Bottomhole location: 1314' FSL, 426' FEL, Section 12, T10N, R12W, S.M. Rig operation commenced: 1200 hours December 4, 1977. Rig released: 0600 hours January 31, 1978. 24-hour test: 218 BOPD, 6 BWPD, 114 MCFD. FINAL REPORT. WELL NAME ., PLFM, , ANNA ~ ,~, f~ , , ?,,?x~~.,,, NUMBER .17 SURVEY TY P E ..... G,,,YR,O, $,'COP, ! C ....... ii ,. , L~,TION R~PORT ) IUS OF CU,xVATUr',u."" ""='- METHOD OF CO;"'.PUT,ATION ;OSCOPIC SURVEY ~PUTED FCR SDC 8Y F,,Y. LI,NDSEY AND ASSOCIATES JA."'.: 25, i978 ;';ELL AF'."XA 17 Kg ?.LEV, t35 'FT. DECLINATIOi'~ 24 DEGREES EAST JOE-11-50-GY~<3-G36 RECORD. CF SURVEY ' ~ ~v~ "' ALL CALCULATIO?.~S PERFO;,,,ED BY I B !4 r:LECTRu',' · ,.~IC C Of'"~PU TER TRU=~ 5. DTIFT VERTICAL SUB umIFT TH.~ANGLE DEPTH SEA DIREC D M DEG, 0 O 0 ~00 ~ 0 ~00 1 30 ~00 2 0 +00 2 15 ~00 2 10 >00 2 15 O0 ~ O 00 4 ~5 O0 ~ 30 O0 3 6~ O0 3 1~ 00 2 15 ,00 2 0 7O0 ! ~ 8O0 1 30 ~00 I 30 :00 2 30 "90 6 lO ,00 7 C .0O 8 30 0.00 99,99 199,97 299,92 399,85 699.78 599.70 699.62 799,47 899.!8 998.85 109~,59 1195o41 1298.27 1398.17 1498,il 1598.06 1698.02 !797,98 !897,94 1997.88 2097,61 2197,07 2296.41 2395.49 -105.00 S12,00E -5,00 SI2.00E 94,97 $44,00W 194,92 S37.00W 294,8~ S39.00W 394,78 494,70 548.00W 594,62 $22,00W 694.,47 $18,00E 794,18': .S29.00E 893,85 528,00E ~93,59 S3C.OOE 1093,41 S30,00E !193.27 S32.00E '1293,17 1393,11 S24.00E la9~,06 SI7,00E ~2 S!4,00E 1593, 1692,98 SI0,00E 1792.94 1892,88 1992,61 $ !.OOW 2092,07 SI3,00E 2!91,ai S39.00E 22~.,~,49 S43,0'~ TOTAL COORDINATES 22,33 S !2,25 W 29,32 S 9,22 W 36,al S '5,37 W a2.70 S 1,88 W 47~98 S 1,16 E 52,4'7 S 3.85 E 56,25 S 6,04 E 59,58 S 7,66 E 62,44 $ '~,73 E 65,17 S 9,49 E 67,94 S 10.08 E 70,53 S 9',90 E 73.9F+ S c,17 E / 81,il 5 ~,73 E 91,41 S 9,82 E 10i.63 S !a.80 E 1il.81 S 23.64 E CLOSURES D I STANCE ANGLE D M ~,00 S 0 0.87 S 11 2,89 S 7 5.70 S 24 9,35 S 29 13.16 S 32 t6,96 S 35 20,85 S 35 25,48 S 28 30.74 S 17 36,80 S 8 42,74 S 2 48,00 S 1 52,6i S 4 56,57 S 6 60,07 S 7 63,04 S 7 65,86 S 8 68.59 S 8 71,22 S 7 74,50 S 7 ~ 1.58 S 6 91,94 S 6 !~;2.70 S 8 11~.28 S ll DOG LEG S,..V~.R l TY DEG/1OOFT 0.000 i,000 0.,501 n 500 ',.7 · 0,250 0,080 0.081 1,012 1.761 ~,75~+ 0,250 0,750 0.500 0.500 0,500 0,250 ~ 500 0,25'0 0,250 0,726 t,000 3,250 0.450 0-915 1.503 SECT ION .DISTANCE O.OC 0.86 2.84 7.83 10,64' 13,24 16,30 21.62 28,76 36,05 42.53 47,97 52.60 56,50 59.9i 62.83 65.6~'v 68.40 70°97 7a.33 81.47 91,82 i02.30 ii2.95 :'.::LL ",;0,, 17 GYF]OSCOFIC SU2V-'¥ o:CORD 0: SUAVEv ALL CA, LCULATIO',¢S. "F'=RF'Gi-iMJD~.. BY ! 5 ~," E~,.._=CTr""~,'~u lC CO.. "'!°UT ER gA,"'.: 25, 1975 '~A~ DRI ~'T ~.,EP TH AhlGLE 2~0 12 2700 15 2~00 17 2900 20 3000 20 3100 20 3200 1~ 3300 19 3400 18 3490 18 3600 '17 3700 18 3800 17 3900 18 4000 20 4100 22 .30 23 O0 25 4400 26 ~+500 26 4600 26 4700 27 4800 27 4900 27 50,00 26 5100' 25 5200 26 5300 26 15 30 0 ~5 0 ~O 15 50 15 50 10 5 50 30 15 0 ~5 30 30 0 30 0 3O 0 15 TRUE VERTICAL SUB DEPTH SEA 2494,!5 2389,15 2592.18 2487.18 258-9.31 2584,31 278=.. 24 2680.~+ 2879.86 2774.86 2973,68 2868.68' 3~o7.42 2962,42 ~161.~6 3056,36 3255,50 3150.60 B350 , 1~ 3245 , 13 343~,45 B330,45 35~0,25 3~35,24 3635.54 3530,54 3730,67 3625,67 3825,68 3720,..8 3920.01 3815,01 4013,21 3908e2i 4105,51 4000.51 4196,59 4091,59 4286,37 418i,37 4375,86 4270.86 4465,25 4360,26 4554.46 4'449 , b~6 4643.36 4538,~6 4732.26 4627,26 4821.56 4716.,56 4911,25 ~8C/g, 25 5001,03 489~,03 5090,72 498'5.72 DRIFT DIREC DEG. TOTAL COO,~ulNATP'S S43.00E 123,72 S 34,75 E 543.00E 138,14 S 48,20 E S42,00E 155.67 S 64.26 E 541,00E 176,78 S .82,94 E 541,005 201.19 S i04,!6 E S4!,'00E 22711:1 S !26.87 E S42.00E 253 9 S 149,94 E S42.00E 278 6 S 172.87 E S36,00z 396, I ' ZV~ZO~:~~''~ ' .~ S28~00~ 422,25 S 295,53 c S20,OOE 450,72 S 308,20 E 517,505 482,13 S 318,86 E S17650~ 516,69 S 329.76 E S16,00E 553,53 S 340,85 E $16,00E 593,20 S ~52,22 E S!6.00E 635,52' S ~64.36 E SI6,00E 678,42 S ~76e66 E S15,OOE 721,60 S 388,63 E S15,00E 765,26 S 400,33 E SI4.00E 809,59 S 411,80 E S14.00E 854.02 S 422.87 E S!2.00E 897,87 S 433.00 E S13.00E 94!.05 S 442.57 E S13.0OE 983.96 S 452.48 E S13,OOE 1027,05 S 462,43 E CLOSURES i~t ~- DI STA?~C: ANGLE D M 128,51 5 15 41 30 E 146,3! S 19 14 13 E 168,41 S 22 25 55 E 195.27 $ '25 8 6 E 226.56 S 27 22 19 260,32 S 29 10 I E' 29/'.4.~ S 30 36 51 E 328,10 S 31 47 45 E 36t,03 S 32 46 56 393.08 S 33~ 42 26 El 421.19 S 34 28 11 454.37 S 35 1 21 E 484,63 S 35 10 38 E 515,40 S 34 59 15 E 546,02 S 34 21. 51 E 578,03 S 33 28 45 E 612',96 S 32 32 48 E 650.06 S 31 37 25 E 689.89 S 30 42 2 732,57 S 29 49 35 E 775,97 S 29 2 '21 E 819,60 S 28 18 20 863,66 S 27 36 56 E 908.31 S 26 57 36 E 952,95 S 26 20 34 E 996,83 S 25 44 44 E 1039,93 S 25 11 14 E 1083.01 S 24 41 44 E 1126,36 S 24 14 22 E DOG LEG SEVERITY DEG/!$OFT 1,750 2.250 .2,501 2.752 2,250 0.500 0°277 0,410 0.500 0,460 0,656 1,091 0.96~ 0.791 1.041 !.775 2,000 0,784 2,750 0'750 0,000 0.322 0,250 0.544 0,500 0.639 0.536 0,250 0.000 SECTIOF DISTANt 125.4- 140,5' 159.0c 181-1~ 206.6' 234.0[ 288,0 313,9~ 338,6:' 359.9'~ 386,02: 411.0!:' 438.0 467.1i 499,12 534.2! 57!.6 6ilo8:~ 654,8;: 698,3:, 742,1: 786,3~ 831,2~ 876.2; 964,22 1051-2( GYF~O$COPIC SURVEY JAN 25, 1978 RECORD OF SURVEY ALL CALCULATiO;:S PERFORF;ED BY i S :~ ELECTRONIC COkiPUTER TRUE ~EAS, DRIFT VERTICAL SUB DRIFT TOTAL COORDINATES C L 0 S U R E S S._~ DIPEC DISTANCE ANGLe :EPTH ANGLE DEPTH D M DEG, D M 5( ) 26 15 5180,al 5075,41 S12.00E 1070.23 S 472,00 E 1169.70 S 23 47 55 E 550.0 26 !5 5270,09 5165,09 S12,0CE i113,50 S 481.19 E 1213.02 S 23 22 17 E 5600 26 30 5359.68 5254,68 $12,00E 1156.95 S 490.43 = 1256.61 S 22 58 ~u E 5700 26 0 5449,57 5344.37 SIO.OOE 1200,36 S 498.87 ~ 1299.90 S 22 34 4 E 5800 26 !5 5539.!5 54~4,!5 S 9.OCE 1243,79 S 506.14 5 1342.83 S 22 8 34 E 5 oo i5 5629.22 5~24.22 S ~.0OE i28e~[~ S ~i2,~3 E 1385.i7 S 21 ~4 3 E sooo is 5719,67 $6i4,s7 s 9.oo is28{$., S ~i9,6i E i z .si s 2i 2i 24 E 6i00 25 15 58i0,11 5705~ii S 9,00E i370(~5 S '22~,28 E ' i468,5i S 2i 0 2 E 6200 25 !5 5900,56 5795,56 S 9,00E i~i3.~>~O.~'=~.. ~S~.,~5 ..... E~ .....1510,26 S 20 S9 5i E 6300 24 15 5991.37 5886.37 S 7.00E i.~.,~¢~:~'%%.'~c,.-r~ ~ 1551.13 S 20 19 30 E 6400 24 0 6082.64 5977.64 s 7.00E i590.93 S 19 59 9 E 65o0 23 45 6!74.08 6069.08 S 5.00E 1535,~~¢¢'5,~,~,,E:~3};~ei630.23 S 19 38 31 E 6700 23 ~5 6357,49 6252,~9 S ~,00E 1~4,85 S 55~,59 E 1707,~3 S 18 57 i5 E 6800 22 45 5449,37 &3~4,37 S 5,00E i65~,20 S 557,59 E 17~5,68 S 18 37' 51 E 6900 22 45 55~,59 6436,59 S 2~50E 1692,78 S 560,22 E 1783,08 S 18 i8 42 E '-30 22 15 6633,98 6528,98 S 3,OOE 1731,01 S 562.06 E 1819,97 S 17 59 19 E O0 22 45 6726,37 6621.37 S 3,00E 1769,22 S 564'06 E 1856.96 S 17 40 59 E 7200 22 30 6818~67 6713,67 $ 2,00E 1807,~p S 565,74 E 1894,12. S 17 22 42 E 7300 22 0 6911.22 6806,22 S 2,00W 1845,51' S 565.74 E 1930,28 $ 17 2 34 5 7400 22 15 7003.86 6898, ..... 6 $ 2, 1883,15 S 564,26 5 1965',87 S 16 40 ~8 = 7500 23 15 7096.08 6991,08 S 4,00W 1921,75 S 562,07 E 2002,26'$ 16 18 10 E 7600 24 15 7187,61 7082.6! $ 8,50W 1961.78 S 557,68 E 2039,51 S 15 52 9 E 7700 25 15 7278.42 7173,42 S 9.0OW 2003,16 $ 551.31 E 2077,64 S 15 23 17 E 7800 26 30 7368,39 7263.39 S 9,00W 20.46.26 S 544,49 E 2!17,46 $ 14 54 2 5 ~" OOW 209i~16 $ 536.57 5 2158,90 S. 14 23 28 E 7900 27 45 7457.39 73~.-4,39 S11, 8000 .27 0 7546~20 744%,20 SI!,OOW 2136,29 S 527,80 E 2200,53 S 13 52 40 E 8100 28 15 76~4,79 752~9~79 S12.00W 2181,73 S 518,55 E 22~2,51 S 13 22 12 E "8200 28 30 7722.78 76L7,78 Sll,OOW 2228,30 S 509,08 E 2285.71 S 12 52 8 E DOG LEG S~V~.RITY DEG/iOOFT ~b~TION DISTANC 0.4a2 1094,'85 0,000 1138.56 0.250 1182.46 0,531 1226,27 0.317 1270,04 l.O00 1313,26 0.000 1355,70 O,000 i398,13 0,000 1440,57 1,055 1482.29 0.250 1523.07 0,~10 156'3,49 0.500 1603,35 0.526 1643~2i 1,011 1682.68 0,967 172!,3a 0.505 1759.6] 0.500 1797,88 0,290 1836.34 0,752 1874.!4 0.260 1911,64. 1,027 1950,06 1,255 1989.78 0 1, 04 2030,74 1,250 2073,39 1,323 2i17,78 0.750 2162,36 1,270 2207.21 0,338 2253,18 GYRO$CCPIC SUF~VEY JAN 25, i97~ - RECORD, OF SURVEY ALL CALCUL/',T IO:',;S PER=''',p:'''-'.,...,,,,,,t-,., BY I .=,... :v.. '-r...LECTr, Ot,:I C- CO"'/PUTE'::',., ., '~'A D 8(2 28 15 8400 28 15 8600 29 30 8700 29 0 8800 29 15 8900 28 0 9008 26 45 9100 26 3O 9200 26 15 9300 26 0 9~00 25 ~0 9500 24 0 9576 24 30 9600 24 0 9700 23 45 O0 24 0 .¢00 23 0 . 10000 22 15 1OO60 22 0 10100 21 0 1.0200 20 15 10300 19 0 10380 17 45 10674 14 50 ~OTTO[',~ HOLE CLOSURE TRUE VERTICAL SUB DRIFT TOTAL CC)ORDINATES C L 0 DEPTH SEA DIREC DISTANCE DEG, . ^OW 781.0,76 770S,76 7898,85 7793,85 Sll,OOW 7986,74 7881.74 8074,09 7969,09 S!O,OOW 8161.34 80.56,34 S!I.OOW 8248,70 6143.70 Sil.OOW 8336,47 823!,47 Si6.00W 8432,38 8327,38 612,50W 8514,62 84.09,62 S!2,50W 8604,21 849~,21 S13,00W 8693.99 8588,99 S15,00W 8784~06 8679,06 S!7~OOW B874.87 8769.87 S19~OOW 894'4, !7 8839,17 Si 8, OOW 8956,05 8861,05 S19,50W 905~49 ~952,49 S22,00W 9148,94 9043,94 S22~00W 9240,64 91~5,64 523,00W 9332,95 9227,9~ $27,00W 9388,53 9283,53 S29,00W 942~74. 9320,74 95!9,33 9414.33 S3!.OOW 9613.52 9508,52 S35,00W 9689.44 9584.44 S39~00W 9971.60 9866,60 $47,82W ~ . 3176'~70 FEET AT S '~, _ .~ S U R E 5 ANGLE D M S 2274.87 S 499~60 E 2321,25 S 490,17 E 2368.09 S 481,06 E 241.5.94 S 472.19 E 2463.99 S 463.29 E s E 2606~:.5~ S 430~60 E 2641.78 S 2646¢~>}¢,:~:% 421,68 E, 2680,09 S 4:!>t~,.~8~ ~ E?~:~,,, 2721 3 8 S 2843,93 S 366.41 E 2867~44 S 2329.08 S 12 23 2372.44 S 11 55 2416,46 S 11 28 2461.66 S 11 3 2507.16 S !0 38 2D52.46 S 10 14 2596,37 S 9 49 9 22 9 3 8 42 8 21 7 59 7 36 7 20 12 E 25 E ~9 E 32 E 55 E 44 E 12 E 51 E 8 E 18 E 9 E i0 E 57 E 29 E 2853.27 S 363.24 E 2876.30 S 2891,1! S 348.90 E 2912,09 S 2928,64 S 333.74 E 2947,59 5 2965,4~ S 318,48 E 298.2,53 S 3000.~4 S 302~22 E 3015,52 S 3020.29' S 291,61 E 3034.33 S 3033,11 S 284,51 E 3046,42 S 3063.61 S 266*90 E 3075.22 S 3091,77 S 248,61 E 3101.75 S 3111.91 S 233.43 E 3120.65 S 3171.77 S 176.81 ~ c 3176.70 S 7 15 18 E 6 52 52 E 630 4 E 6 7 47 E 545 7 E 5 30 54 E 5 21 31 E 4 58 44 E 4 35 50 E 4 !7 23 E 3 il 26 E 3 !1 25 E DOG LEG SEVERITY DEGiiOOFT 0'.336 0.473 0,500 0.788 0.552 0,250 i.665 1.331 0.272 0.268 0,458 0.622 1.536 0,696 2,326 0,476 0.250 1~012 0.944 0,626 2.500 0.787 1.320 1.~30 1.009 SECTION DISTANC 2299,1; 2344,9; 2591.tq 243g,4F 2485,9! 2533.i~ 2579.0~ 2626.3L 2666,0:~ 2708.7' 2750,S'. 279!.8~! 2830,9'i 2859,9: 2869,06 2942~6~ 2978.6~ ~012,5 3031.~ 304~,2 3073.7~ 3100.~ 3 120, { 3176.~ GYf:!"c'CC.;P.,j,> [ C SU!:;VEY .... .. ~-"'~'~m ~_ A"D CLOSURES FOR GIV£~'' D~°TH$ I?,:TE:{.~OL,,-',T='D T,',,UE \:n;'-~TiCAL DEP'FH~', ,..,-,,-,~',,..'INAT~S :', TRUE CC;DE XEASURED VE:~T ICAL ~ A!'-i E DE P T H DE P TH CLOSURE D !STAF:CE ANGLE D M S SUB SEA 9108 8521,78 2650.20 S 420,93 E 9575 8944.17 2343.93 S 356,41 E 10420 9727.58 3121,21 S 225~75 E 2685.42 S 9 1 30 E 8416.78 2867,44 S 7 20 29 E 8839.!7 B]29.~7 S 4 8 13 E 9622.58 D ~'~ P TH. 1 ? 7 ~': vErsT I CAL ~.. ~- ,..~. ¢ .. TOTAL COORD I ?',:AT E S 205 205. a05 405, 505 505, 605 605, 705 705, 806 805. 905 90.5, '~,,6 10'35 . 11,06 1105, 1207 12C):,5 I~07 1305. 1407 1405. 1607 1605, 1707 1705 &07 i~.n'~ 1907 1~05, 2007 2005~ 2107 2105, 2208 22051 230a 2305 2410 2405. 2511 2505, 2513 2605, 2715 2705. 2~21 2805~ 2927 2905. 3033 300~, .3140 3105, 3246 3205. 33B2 3305, 3a58 3405 3563 36.58 3605 1 CO 200 300 ilO0 50O 600 700 800 9OO 1000 1100 1200 1300 1500 l~nO 1700 i 900 20CO 2ZOO 2200 2300 2400 2~00 2500 27OO 2SO0 2900 "..,000 ': 3!00 ~ 3200 3300 ,. 3z:O0 2.95 S 0.4S 5.32 $ 2.48 8.26 S 4.78 11.20 S 7.26 13,94 S 9.98 17~].8 $ 12.14 22,70 S 12,13 29.74 S 8,98 36.82 S 5,15 43,04 S 1,69 48.3i S 1.35 52.74 S 4,02 ,,, ~,b2.61 5 8.78 68,12 S 10,11 70,71 S 9,84 74,25 S 9,14 81,82 S 8.73 92.25 S 10,02 102,46 S 15'47 112.86 S 24.62 125~17 S 36.10 140,29 6 50.14 158.79 S 67,07 181,62 S 87.15 208,12 S 1!0,18 236.00 S 134.46 263.64 S 159.17 290,3/+ S 193.29 315,~9 S 207.22 340.09 S 231.23 '3 E,'~ S 253.67 38S,i6 S 273,31 W W W W W W W W W W E E E E E E E E E E E E E E E E E E E E ', .' E'. L L "'~" ','-.'iASUk~'O :Dc:oTH AND OTP (:Y'?,OSCO? ~. C DATA Fvx EVE;-:,~ EVE,',~ ].00-FE~"T cF SU~ SEA DE~,TH, J A !"..: ~ 97° TRUE MEASURED VE°TICAL~, DEPTH DEPTH F<D-I'VD VERT I CAL DIFFERENCE CORRECTIOPl TOTAL .,.,RD I r.qATES 8773 5705, 3878 3805. 3954 3905, 4091 4005. 4199 4105, 4509 4205° 4421 4305, 4533 4405~ 4644 4505. 4757 4605, 4859 4705~ 4931 4805, 5093 5204 5005* 5316 5105o 5a27 5205. 5539 5305. o.~1 5405, -5762 5505. 5873 5605, .... 5984 5705, 6094 5805. 62.0 5905, 6315 6005, 6424 6105, 6534 6205, 6643 6305, 6752 6405, 6860 6505, ~:'" 6400 6969 6605, 7077 670 . 7185 6805 72~3 6905~ · ~' 7401 7005 · 7510 7105, 3600 68 3700 7S 38.00 79 3900 86 4000 94 4100 104 4200 116 4300 127 4400 139' 4500 !51 4600 164 4700 176 z~SO0 188 4900 199 5000 211 5100 222 5200 233 5300 246 5400 256 5500 268 5600 279 5700 289 5800 300 5900 310 6000 319 6100 329 6200 337 6900 347 355 6500 364 6600 371 6700 380 6800 388 6900 396 7COO 404 6 5 6 7 10 12 11 12 12 13 415,00 S 444,22 S 476,92 S 513,54 S 553,21 S 596~ 96 S 644,45 S 692~4t S 740,77 S 790,32 S 840,33 S 11 1130,37 S 13 1178.97 S 10 1227,20 S 12 1275.27 S ll 1~22.00 S 10 1368,44 S 11 1415.16 S 10 1460,64 S 9 1504.80 S 10 1548.87 S 8 1591,97 $ 10 1635,4-3 S 8 1677,34 9 1719 · 12 S 7 1760,30 S 9 1801,91 S 8 1842,,59 $ 8 1883.52 S 8 1925,58 291.50 E 305.71 E 317,09 E 328,47 E 340.5& E 353,30 E 366, ~ E 380,63 E 393,77 E 405~,1 E 419 ~ 4.5 E 431~ 20 ': 441,88 E 452,88 E 464,00 E 474,48 E 484,78 E 494,91 E 503 ~ 45 E 5i1,12 E 518,52 E 525~88 E 533,28 E 539,53 E 544,91 E 549~ 17 E 552,88 E 556, 13 E 559~35 E 561 , 30 E 563,59 E 565~53 E 565~82 E 564~25 E 561~79 E ~VEKY EVE,".; 1'0.9 F"ET OF SU~. SE'A 197C; -' DE? TH VF:.RT!CAL SU~) DEPTH StEt, F:D---T',,'D VE:TT I CAL D I FFETE~'iCE CORRECTION TOIAL COCRD I~N ,~qT ES 7619 7729 7841 7954 8056 8293 8521 8635 ~750 8864 8977 9089 9201 9~,23 9643 '97~2 9851 9970 ~0078 10185 ~029Z 10396 10501 10~05 7205, 7!00 414 7305, 7200 424 7405, 7:,~uO 7505, 7400 449 7609, 7500 461 7705, 7600 474. 7805, 7'700 7905. 7800 501 8005~ 7900 51.5 8].05. 8000 53C) 8205, 8100 544 8305, 8200 559 8405, 8300 572 8505, 8400 584 8605, 8500 596 8705, 8600 607 8805' 8700 618 8905, 8800 627 9005, 8900 638 9105~ 9000 646 9205, 9100 656 9305, 9200 665 9405, 9300 673 9505, 94'00 680 9605, 9500 686 97094 9600 691 9805, 9700 696 9905, 9800 700 10 1969,53 S lO 2015.46 11 2064,47 S 14 2115.53 S 12 2166,09' 13 22!8,83 S 14 2271,62 S 13 2324.49 S I 14 2377,96 15 2432.~6 S 14 2z~8..7, $0 S 2541,89 S 11 2783,92 S 9 2827, 09 S 1% 2869,56 S 8 2910,55 S 10 2951.S2 S 9 2990,04 S 8 3026,04 S 7 ~059,06 S 6 3089,36 S 5 Sl15.67 5 3138,97 S 4' 3159~71 S 556.58 549.37 541,47 531.83 521,83 510,94 500,29 489.54 479,16 458,66 44'7,26 43~66 423,05 4'11,79 399,85 386.33 371,97 357,42 341,04 324,43 307,34 288,42 269,62 250,29 230.36 210,21 190,31 E E E E E E E E £ E E E E E E TRUE DEP TI-! DEPTH 1000 998, 2000 1'997. 3000 2973, 4000 392.0, 50~0 4221. 50~0 5719. 7000 6633, 8000 75~6. 9000 8A25, OOOO 9332, !O,Ju FEi!iT S SEA IB92, 38!5, 4716, 5614, 6528. 7A4!. 8320. 9227. OF ,',iE,t'.SU,Ct~--[~ DEPTH. TOTAL COORDINATES 73 227 482 897 1328 1731 2136 2502 3O00 · 41 S 5,37 W ,94 S 9.17 E .31 S 126.87 E ,,!.7 S 3!5,73 E .87 S 433,00 E ,F.'.3 S 519.61 E · 0l S 561.89 E · 29 S 527,80 E .98 S 43t.57 E .~+ .S 302.22 E ' ' ' ' ' ' : "---~'- ~'--~'~'--' I:'-~'--t-'~'~--~-, --~"-'T~ , ' j ~ : · · /-- ' ....· ~ ' -: .......... ; ~-, ~'--. ......... I"':': : i ;-"i -:-:: .-t.'.SCALE ~1 =500, ?" ' : }-:-'~: .... ~ .-;":',:'~)'"~ .... ~ ........ V'¥~"~'~'~;~'~_~?}7'L;.: :AMOCO PRODUCTION COMPANY-~ ' :'~ ...... ~" ~-i:- ?.. ~'..-:~:::: .¥i::?::'.':::':¢i.-':~-:'.~.::~.-t ...... ~-~..... I'" ...... WELL - ANNA I* ~ . .......................... : ............. ~-':-"~'-~'-'~-'~ ......... , ~ · RADIUS ,OF CURVATUR~ ........... --. 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' i .... ~ ~ ' '- , ' ..... , .......... . ....... , ................ , , , -.-,' i-' ............... . .......... .............................. ,, . , ,,,, ., , ...................... ~... ~ , ~ I . , ~ . .._ I ] ................................ ~-"I .... ~-" ............. 7"~T~-~~' ' ' ~ ' ' ~-~ -~ ....... ~ ...... ~ ...... } ........... ~"~ I~ .... .. ........... · -- ~ , . , i - ' , .,-. '. { '" ....... ~ : ' ' I ~ ......... : ....... ~ ............. '. ~1 ' ' 2 . - ~ ....... ' ' ' ' I ' ~ ....... ~ ' ' " ' ~ . ' ~ .... ~ '/,, ~'~ ..... ; ': .... . I .... ' --~ .... ' . ' i ' I ¢~ . -: ' -' '.- -i .................. ' ............ ~-' ' I i I ' ' ~U~ .....[ ....... L -~ -1 ........ ; ~ .... . ' - . .; ..... --~ ............ ~-...i.--i :. ~ : ) ' '" _~ ~ i t i .-L- .L._.L...I__ _L.;. ~ ......... , ..... ', ' ,~oo.--'-' '---~ ~..~._, , ..... ~ ; ..~'- :~ ~- -, - -- - -.~-- ' ~ ~ ~ ~ ' ; ' ....... ' ' .... ' ' L ' '" / ~ ', ' t ' _ .... ~_.'_~ ........ ~ J. ~_ ~... " .... .... ":' ' '"' i¥'- ---~ -. ~-~--~ :-- v:~" ;:', ~- - t .... ~ ........ ....i.J__L.. ~ '['-' ~"~ , ' ~_-~"'i_ ........ : '.-~- ' ..... ~' ~ ' ' ~oo I - . -'- , .~ _:_i ...... :-- i: .~ · , · !,',~-i-t :'~: ' ': ': ''- ' , · ~_ -. I .......... ' " : ..... :'";'-P' . ' ~ · ~ ...... ~ ' ! '- I ~ :- .. ~ ~ ~ :"' ' r ' I ~ ' .' ' ' --~ .... ~ ...... , .....'''~ ~MD''10,6~4 ' I' " '' I 1 ':' [ ' ' ' i ' ' '.. ..... .:. , ~ ~ ........................... ' " ~ ' t ' ~ '- · -'. ...... t .,. , ' ~ '' ~ ~ ~ .... ~ .... ........... '.-'7 ..... ' .... ~-~ .... ....... ~'"~'"~''-. -~ '~-- '~ .......... ...... ~ '- ' i ~' : , ',.-~ ~. ' .~ . ', ~ , . . t ..... : ' ',' ~. ' . .-~. , ...... ~.,-. ~.,~ ~-., .~ ........ ].: ;..'..t-.~-' ....... :.' ..... ~--l.:- ..... .............................. I / i . I -' ) · ,-~ ......... ~ ..... SCALE '; I": I000' ~ AMOCO PRODUCTION COMPANY..- WELL- ANNA 17 'i'i~-'RADIUS OF CURVATURE 'ROSCOPIC ~LL !DEPTHS s"oWN ARE r TVD.- ..... i . L. A. Darsow Area Superintendent March 13, 1978 File: LAD-278-WF Mr. O. K. Gilbreth, Jr., Director Division of Oil and Gas Conservation Department of Natural Resources State of Alaska 3001 Porcupine Street Anchorage, Alaska 99501 Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 Dear Sir: Monthly Report of Drilling and Workover Operations Granite Point 18742 Well No. 17 Please find attached State of Alaska Form P-4 summarizing drilling operations on Granite Point 18742 Well No. 17 for the month of February 1978. Very truly yours, L. A. Darsow Area Superintendent At t achment DMS:sls Form No. REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. APl NUMERICAL CODE 50-133-20311 6. LEASE DESIGNATION AND SERIAL NO. ADL 18742 1. 7. IF INDIAN'ALOTTEE OR TRIBE NAME OIL ~'~ GAS [] WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT FARM OR LENSE NAME Company Granite Point State 18742 Amoco Production 3. ADDRESS OF OPERATOR 9. WELL NO. P.O. Box 779, Anchorage, _&laska 99510 17 10. FIELD AND POOL, OR WILDCAT Granite Point 4. LOCATION OF WELL Leg 2, Slot 6, Platform Anna, 794' FNL, 603' FEL, Section 12, TiON, R12W, S.M. 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 12, T10N, R12W, S.M. 12. PERMIT NO. 77-75 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Status as of FebrUary 1, 1978 February 2 to 14 February 15 to 18 February 20 to 28 PBTD: 10400' Pumping PBTD: 10400' Pumping PBTD: 10400' SI for BHP Survey PBTD: 10400' Pumping Status as of March 1, 1978 PBTD: 10400' Pumping RECEIVED NIAR 1 5 1978 Division o! 0i~ and G~*~ uons~';rv?.ti3a 14. I hereby ce~,tif~t t~L~for~oil~'is ~e and correct SIGNED .~'~/ ~'/- ,,/-"~"~"~ TITLE Area Superintendent March 13, 1978 DATE · Ill I I II II II I I II III I NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committ~ by the 15th of the succe~ling month,unl~ otherwise dir~t~i. L. A. Darsow Area Superintendent February 20, 1978 File: LAD-199-WF Mr. O. K. Gilbreth, Jr., Director Division of Oil and Gas Conservation Department of Natural Resources State of Alaska 3001 Porcupine Street Anchorage, Alaska 99501 Amoco Production P.o. Box 77e Anchorage, Alaska 9951 Dear Sir: Monthly Report of Drilling and Workover Operations Granite Point 18742 Well No. 17 Please find attached State of Alaska Form P-4 summarizing drilling operations on Granite Point 18742 Well No. 17 for the month of January 1978. Very truly yours, L. A. Darsow Area Superintendent Attachment DMS:mls For m ~No..~P-4 REV. ~- ~-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. APl NUMERICAL CODE 50-133-20311 3. ADDRESS OF OPERATOR P. O. Box 779, Anchorage, AK 99510 6. LEASE DESIGNATION AND SERIAL NO. ADL 18742 WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Amoco Production Company Granite Point State 18742 9. WELL NO. 17 4. LOCATIONOFWELL Leg 2, Slot 6, Platform Anna, 794' FNL, 603' FEL, Section 12, T10N, R12W, S. M.' 10. FIELD AND POOL, OR WIL~AT Granite Point '"11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 12, T10N, R12W, S.M. 12. PERMIT NO. 77-75 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Status as of january 1, 1978 January 2-16 January 17 January 18-19 January 20-21 TD: 8316' TD: 10674' TD: 10674' TD: 10674' TD: 10674' January 22-23 January 24 Jauuary 25-27 PB~TD: 10400' PBTD: 10400' PBTD: 10400' JanuarY 28-30 Janua<y 31 PBTD: 10400' PBTD: 10400' Status as of February 1, 1978 PBTD: 10400' Drilling 12-1/.4" hole. Drilling 12-1/4" hole. · TO and run:~IES log, BHC log and..dipmeter. Fish and recover dipmeter. Run 10,663' 9-5/8" casing, 254 jts. (40#, 43.5#, 47,5# S-95 Butt x N-80 Butt) Cement with 1285 s× class G cement, NU and test BOP, install and test tbs. spool. Drilling out cement to 10,400' Run Gyro Survey, GR-CBL-CCL Perforate 9660-9725 10,134-10,144 9758-9832 10,212-10,272 3 JSPF 10,'098-10,100 10,318-10,334 10,114-10,124 Pull drillpipe, prepare to run BHA, kill well. Run Kobe BHA, set at 9500', mule shoe landed at 10,349', well on pump, rig released 0600 hours. Pumping. RECEIVED FEB 2 2 1978 Division oi Oil ~nc! Ga~ uur~s~rvztio~ Anchoraoe 14. I hereby c7~ th~~_~t._ SIGNED. / ~ ·, _ _ TITLE Area Superintendent 2-20-78 DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. SCHLUMBERGER oFFSHORE SERVICES a Division of Schlumberger Limited HOUSTON. TEXAS 7700! PLEASE REPLY TO FEBRUARY 14, 1978 SCHLUMBE;RGEROIrFSHOR[SERVICEI 500 W. INTERNATIONAL AIRPORT RD. ANCHORAGE, ALASKA 99502 i , AMOCO PiRiOD. UCT t0N COMP.ANY . P.O, BOX 779 . ANCHORAGE, ALASKA 99510 Attention: Gentlemen: 1 RFOLDED SEPIA Enclosed are 2 B Lprints of the Company AMOCO PRODUCTION CO. Field. GR AN I T E PO I NT DI L, BHC/GR.... on: ,Well GRANITE POINT STATE 18742 #17 , ,County KENAI State ALASKA 1 RfO~r~lT~hln~s are being sent to: 1 B Lnrints AMOC(~ PRODUCT ION COMPANY .1010 SECURITY LIFE BUILDING DENVER, COLORADO 80202 ..ATT ENTI'ON- A. M. RONEY . 2 BL prints PHILLIPS PETROLEUM ¢OHPANY .... 1010 SECURITY LIFE BUILDING .... DENVER, COLORADO 80202 ..ATTENTION- J~ P. DENNY RFOLDED SEPIA prints ATLANT I C R I CHF I ELD COMPANY P.O. BOX 360 iANCHORAGE, ALASKA 99510 ..ATTENT tON - D. W. BOSE 1 RROLLED SEPIA 1 BLprints CHEVRON U.S.A.,INC. P.O. BOX 7-839 ANCHORAGE, ALASKA 99510 ATTENTION-CHARLES F. KIRKVOLD 2 BL ETT~rints G 0 I.L COMPANY 1860 LINCOLN STREET ..DENVER, COLORADO 80203 ATTENTION-J. E, HOFMANN · 1 .RFOLDED SEPIA ~t_BLprints DEPT. OF NATURAL RESOURCES DIV_ OF OIL ~, GAS CONSERVATION ~001 PORCUPINE DRIVE ANCHORAGE; ALASKA 99501 ATTFNT!ON- O: K~_ G!I_RRFTH prints prints REC iVED . . The film is. RETURNED TO AMOCO We appreciate the privilege of serving you. RECEIVED COMPANY- DATE- Very truly yours, SCHLUMBERGER OFFSHORE SERVICES / /SALES ENGINEER L. A. Darsow Area Superintendent January 18, 1978 File: LAD-069-WF Mr. O. K. Gilbreth, Jr., Director Division of Oil and Gas Conservation Department of Natural Resources State ofAlaska 3001 Porcupine Drive Anchorage, Alaska 99501 Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 ~---~_C.~_(~_' !. Dear Sir: Monthly Report of Drilling and Workover Operations Granite Point 18742 Well No. 17 Please find attached State of Alaska Form P-4 summarizing drilling operations on Granite Point 18742 Well No. 17 for the month of December, 1977. Very truly yours, L. A. DarsOw Area Superintendent DMS:mls ~,. ' SUBMIT IN DUPLICATE ForUm No. P-4 REV. 3-1-70 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. APl NUMERICAL CODE 50-133-20311 6. LEASE DESIGNATION AND SERIAL NO. ADL 18742 1. 7. IF INDIAN'ALOTTEE OR TRIBE NAME OIL Gt OAS [5] 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Amoco Production Company Granite Point State 18742 3. ADDRESS OF OPERATOR 9. WELL NO. P. O. Box 779, Anchorage, Alaska 99510 17 4. LOCATIONOFWELL Leg 2, Slot 6, Platform Anna, 794' FNL, 603' FEL, Section 12, T10N, R12W, S. M. 10. FIELD AND POOL, OR WIL~AT Granite Point 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 12, T10N, R12W, S. M. 12. PERMIT NO. 77-75 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED~ PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. December 4, 1977 December 5 Rig up. December 6 TD: 282 December 7 TD: 625 December 8 TD: 625 Rig Operations commenced. December 9 TD: 611 December 10 to 11 TD: 2048 December 12 to 13 TD: 3530 December 14 to 15 TD: 3530 December 16 to 17 TD: 3530 December 18 TD: 3530 December 19 TD: 3671 December 20 TD: 3880 December 21 to 31 TD: 8316 Drilling 26" hole. Dyna-drill 282-312', drilling, Gyro Survey RU and run 15 jts. 20" casing, set at 610',cement with 1263 sx class 'G' cement, and NU 20" head. NU BOP, Drill 20" shoe. Drilling, Dynadrill 12-1/4" hole to 2048. Drilling 12-1/4" hole. Open hole to 17-1/2" (2872'-3100'). Run 90 its. of 13-3/8" casing, landed at 3514', cement with. 2354 sx class 'G' cement. NU and test BOP's. Tested casing at 1500 psi, drilling out cement, run Gyro Survey. Drilling 12-1/4" hole. Dynadrill 3671-3790 drilling. Drilling 12-1/4" hole. Status as of January 1, 1978 TD: 8479 Drilling 12-1/4" hole. REC :iV[::D 2 0 A P. C'. h o :' ? 7. '~ 14. I hereby cerDh~,~ f~~~..~ SIGNED. .-%/_ . . TITLE Area Superintendent DATE 1-18-78 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. L. A. Darsow Area Superintendent December 8, 1977. Pile: LAD-IO15-WF Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 Mr. O. K. Gilbreth, Director Division of Oil and Gas Conservation Depar~memt of Natural Resources State'of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: /2 ./c / ! / Notice of Change in Surface Location Granite' Point 18742 Well No. 17 Reference is to-a telephone conversation of December 5, 1977 between your Mr. John Miller and Amoco's Jim McMaster. During this conver- sation, Amoco requested and was granted verbal approval to'change the surface location for subject well from Slot 6 to Slot 5 in Leg 2, Platform Anna. Attached please find a Form 10-403 Confirming that change. For your information, subject well was spudded on December 6, 1977. We anticipate~being in a position to'nipple up and test the BOP stack late during the week of December 12, and will advise of the exact time and dare'next week, so that a State-inspector may be on hand to witness the test. Yours very truly, L. A. Darsow Area Superintendent Attachment' WRH:klt Form 10-403 ~EV. 1-10-73 Submit 'lntentlo,,;s" In Triplicate & '*Subsequent I~v.orts' In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY· NOTICES AND REpORTs ON WELLS (Do not use this form for proposals to drill -or to deepen Use "APPLICATION .FOR PERMIT--" for such proposals,) GAS r-"] OWIEkL WELL OTHER 2. NAME OF OPERATOR Amoco Production Company 3. ADDRESS OE OPERATOR P. O. Box 779, Anchorage, Alaska 99510 4. LOCATION OF WELL Atsu;rface Leg 2, Slot 5, Platform Anna, 795' FNL, 599' 'FEL, Section 12, T10N, R12W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 105 ' RKB-MSL 14. Check ApproPriate Box To Indicate Nature of Notice, R.e 5. APl NUMERICAL CODE 50-133-20311 6. LEASE DESIGNATION AND SERIAL NO. ADL 18742 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UN)T, FARM OR LEASE NAME Granite Point State 18742 9. W~LL NO. 17 10. FIELD AND POOL, OR WILDCAT Granite Point S~EC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 12, T10N, R12W, S.M. 12. PERMIT NO, 77-75 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER 5HUT-OFF r-~ pULL OR ALTER CASING · , FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR AcIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* · (Other) Chan~e of surface location' (NOTEz Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. Subject well was permitted to drill from Leg 2, Slot 6 on Granite Point Platform Anna. Because Slot '6 is too near a pipeline pig launcher, operator moved the surfaCe location from Slot 6 to Slot 5. Verbal approval for this change was obtained by phone conversation December 5, 1977 between yOur Mr. John Miller and Amoco's Jim McMaster. 16. I hereby certifY that the foregoing Is true and correct TITLE Area Superintendent DATE December 8, 1977 (This space for State office Use) See Instructions On Reverse Side Returned Bszmit No. 77-75 re~~ ~ at a ~ in Secttc~ 12, Tcmm~hip 1~, ~ 12W, S.M. offic~ within ~ ~ ~ the well is ~. ~ would also like to be nottfie~ so that a re~~ of the Divisic~ may be pzesent to witness O. K. ~, Jr. ~ of Fish ~ ~, m~ttat sectic~ w/o ~cl. ~t of ~-~ w/o e~cl. Divtsic~ w/o ~.~ Mobil' Oil 'Co-rporatiOn Amoco Production Company P. O. Box 779 · Anchorage, Alaska 99510' Attention'. Mr..L.A. Darsow L,,-1 p P.O. l~OX M4,I DENVER. G()LOI{ADO 80217 . November 30, 1977. IZOd_c. ~ac;;~- l_7712 ~'o ~';"! I /.~ ~;-~; / I / I~ PROPOSED LOCATION G~NITE POINT 18742 WELL NO. 17 COOK INLET, ALASKA Gentlemen' Reference is .made to your letter of November 23, 1977, to our Mr.. W. G' Sole, proposing subject well to be drilled to a bottom hole location on~ top of the C-8 at 1500' FSL and 300' FEL of Section 12-10N-12WSM. This is to advise that Mobil has no objection to this proposed location. Yours very truly, .A.J. McCredie, Division Regulatory Engineer Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 L. A. Darsow Area Superintendent November 23, 1977 File: LAD-986-WF Mr. O. K. Gilbreth, Director Division of Oil and Gas Conservation Department of Natural Resources State'of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear sir: Notice of Intent to'Drill Granite'Point State18742 Well No. 17 Cook Inlet, Alaska ------D,--f c. c.:.OL 1' '/ 2 L'NG ~ 3 4 2 G~fOL 3 G~OL REV DRAFT .. SEC i :-ONFER: . Please find attached the State Form 10-401, Application for Permit to' Drill, for the above mentioned well. Well No. 17 will be drilled from Leg 2, Slot 6 of Platform Anna toa bottom hole location of 1500' FSL, 300' FEL, Section 12, T10N, R12W, S.M. at the top of the C-8 zone -9600' MSL. All zones through the C-8 will be drilled, evaluated and selectively perforated, and stimulated if necessary. The well will be completed as a producer. Since this is the third well to be completed in the southeast quarter of Section 12, we hereby request administrative approval for this location. Also attached is a draft in the amount of $100 to cover the filing fee. In addition, a location plat of the Granite'Point Field and sketches of the 20" and 12" BOP stacks have been included. We anticipate being in position to-spud this well sometime during the week of December 5, 1977. Yours very truly, Area Superintendent Attachments GWU:klt RECEIVED NOV 3 5 1977 . Form 10-401 REV. 1-1-71 la. TYPE OF WORK STATE OF ALASKA 'OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN SUBMIT IN TRIP ,'E (Other instruction., .,n DRILL ~ DEEPEN r-] b. TYPE'OF WELL OIL [-~ GAS [~ WELL ~ WELL* OTilER 2. NAME OF OPERATOR Amoco Production Company 3. ADDRESS OF OPI.'.;RATOR ' P. O. Box 779, Anchorage, Alaska reverse side) SINGLE MI. II.T1PLE ZONE [] ZON E3 99510 4. LOCAT,ON OF~VELL Atsurface keg 2, Slot.6, Platform Anna, 794' FNL, 603' FEL, Section 12, T10N, R12W, S.M. ^tpr°p°se0pr°d'z°nel500' FSL, 300' FEL, Section 12, T10N, R12W. S.M. at 9600' -M.RT. .... 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 7-1/2 miles southwest of Tyonek, Alaska 14, BOND INFORMATION: TYPE Blanket Surety and/or No. API No. 50-133-20311 6. LEASE DESIGNATION AND SERIAL NO. ADL 18742 · 7. Ili INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LI".AgI:. NAMI,'. Granite Point S~ate 18742 9. ~VELL NO. 17 10. FIELD AND POOL, OR WILI)('AI' Granite Point 11. SEC., T., R., M., (BOTTOM HOLE OB$ ECTIVE) Sec..12, T10N) R12W, S..M.~ 12. Amou., $100,000 15. DISTANCE FROM PROPOSED * 1500 ' north of lease LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT.boundary which is (Also to nearest 0rig, unit, ir:,.n~0South line of Sec. 12 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 1300' S, SW of 18742 Well No. 29 21. ELEVATIONS (Showy whether DF, RT, CR, etc.) 105 ' RKB-MSL 16. No. OF ACR~ IN LEASE 5060 19.PROPOSED DE~'II 10,700' 23. PROPOSED CASING AND CEMENTING PROGRAM NO.ACRES ASSI(;NED TO TillS WELL .collapse, tension and burst respectively. 53 20. ROTARY OR ('.'AI~LF~ TOOLS Rotary 22. APPROX. DATE WORK WILL START December 7, 1977 SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE S'ETTING DF. PTH Quantity of cement .... .. . 26" 20" .91.5# 5LX-42 ..600' . To surface 7-1/2" 13-3/8" 68.61.54,5# K-55 3,500' To surface 2-1/fi" 9-5/8" 43.5, 40# S-95 & 10,700' 500' abov.e upper pay . 'N-80,. 0.TE: ' Casir g deSign will provide f(,r design safety ..fa.c.~( rs of '1.125, 1'.8 and 1.0 for Operator proposes to directionally drill Well No. 17 from Leg 2, Slot 6 of Granite Point Platform Anna. Ail zones through the C-8 will be drilled, evaluated, selectively perforated and stimulated if necessary. The well will be completed as a producer. The location plat and sketches of BOP stack arrangements are attached. · IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data o~ present productive zone and prop,,~cd new productive zone. If proposal is to drill or deepen directionally, give pertinent data on snbsurfaee Iocatious an0 nleastll'e0 and title vertical depths. Give blowout preventer program. 24. I hereby cel:tify that t~/Fogegoing is True and Corre~i,t'--'N .. ~ SICNED /t~",--.~)C&.~.,.,.,,_., /'~'-..//~ ~ 1977 ,":" /..... . ~- ~/ ~ , DATE.. November 23, (This space for Sta(~ office use) / ~NDITIONS OF APPROVAL. IF ANY: sm~m ,~ cO~ c,,~s ~O~m~ I ~Vo ~oo OT~ ~ ~ ~ ~9 ' ff ~ ~ [ ~ YES ~ NO DIR~~~~D A.P.I. NUMERICAL CODE ~VES ~ ~o 50--~33--203~Z PERMI~ ~ ~ ~ -75 ~PROVAL DATE ~ ~Se~ Imtru~tion On ~er~e Side T,.ri.E_A~ffa Superintendent 1, 1977 DA'rE AMOCO Amoco Production Comp.ny ENGINEERING CHART' j ! . ] RECEIVED , DlvI~Io. Of ~1~ & 8,~ Conservation SHEET NO. FILE OF APPN ~v~ Amoco Production Comk .]y ,tlMOCO~ ENGINEERING CHART SHEET NO. FILE OF APPN DATE BY 3-14-77 PAN'AM ET HBp · 9700 Est -' · TMD 9947 TV D 2.5(4 10,§73 TVD · 24 lip,077 TM~ 10,0:>8 TVD 9889 TVD,~ -88~ / '8914 / TblD 9409 TVD ND 0 0 I I 0 0 0 I , 10,330 TMD I0,101 TVD -9469 23(4-3 8656 ®, 7 /t5(4- 4) · , I0 800 TMD 9'507 TVD 11,524 11,485 10,487 TVD I x,., I 22-1 8999 / / / / / / / / / / 11,150 TMD TVD R CEIVED lO · .. ' . P.O. Box 779 - .7 :' A~chorgge, Alaska 9950'1 ; ".'- .... -' : '~: :'· January 10, 1969 · '" ', -':"~-L'-- ':i ...... ,' :~.. · · ~ .:.~ ~ , .~. ~'. . 5 .,- . ~....: . ~ .. .,' .~ . , -. ..... ~ .-.: .~.: ., . G. P. State 187z~2 Well No~_lY_ - , ~ ~g J, Slot"4, G.' F.' "Ai' · · . , 300i' Porcupin~ Drive-i· ::,-.<.:-:. ..... ·; ,.-,...,, '-'., -; - . . -' Anchora~ei-.'At:a~a5 ~i~:' 99504.-'~:~:,, t~' ~: ...':..,~ :,. ?.<'>,~? . ~ :.... · - -. , . .Dear-~;...Burr~ll...,.,~,.~,~. · ..... ...... ,~ ,-. .... ,.. . , .... , ..'.'j '. ~ 't;'.., ~, ..e ,.e.~. ,- '{. 5-' ;.'c~ '~',/.~% ['t'._ ..., . '.,' $ ,.,. ~- .3. ' .. ','~ - ' " .4¥ '. ~ :,' ..... ":~. "," F5 : ." '~ .~:',::~.' . ~,"'? ,'.L,?;,5 :.5 '7. '; '~ · ',.' -ment of the.,?piatfOrm-'.ln;":view..:of les~: than :optimum penetration of re. in:for'ein~'Casin~".~t~ing*~"w~lls ha.~>~t b~en authorized or d~- .~-,~5~.-,ignated/.~o~..the::pa~tieula~:.:.drillin'~:.~lots..~ ·With Mr. Marshall s '.~-~-..'-.. ,' .' ,~'~'~g'~t' ' '-:5 ? '-' '.. "." .,' '.= - . :" · .,~' ...... : ' ' ' " '. ' ?; . '. . '. ~ ~.',.~-:-' 't,..~' ~../ .:-;:,' .-. ,. ~:t,.'; .-~ .% . 5' ' ;.. . ' ' ' t ' ' "':',':'"t'?i"?;'~?-In:',th~,:easei.of~:'-~eg":-.B,.,'B'lOt-' 4i~,.on...~'. P.-' Platfom A , which "~.Was' tentatively .planned'-~as tt~e:'surface:'location of G, P. State, , "'lS~42J~{{~ll-N0'~. l~"~. :it?.~a~[~Ia~*r'.de~i'ded not.tO.drill Well No. 17 .and a .permtt.~W~' ~ver/.-applied for.-:.With Mr. VonderAhe .s verba · con~ ;.'t6"~r. '~itmafi, th-~S.'~ ietter'~ill':serve as notification ~,~h~t-'a holeV'was:-drill*d id.~'~-~g 3, Sio~ .~, and that 13-3/8" 6asing Was,~Set..,::a~ -. 2015 ,:::,,W! th,~..c~ment.~ C ~rcula tod to. th~' surface. ~e cement ' ' ~a's:: ~ ve'r:.':d~il!ed~:ou~'~'-0f. th6.~":~i'3"3/8'.,:" casing a~d Mr, 'VonderAhe indi- "" '"" di'tld thi~/:.:t~tS,:.~oula..'Sait~fy.'-tho',sta~s requirementu for plugging -~''~',.. ,p~ioz "t0 ab~ndo~en~,'O.f the-~hole.f,"'Since a pemit was never issued, letter.:notifi~atiOn.';$s,being submitted in lieu of Form ..~. ~'"::' "t'.'-:'~-;%':~ -' -'-Yours very truly, [... ~ ~.:.' '. ~-.'- '~'+' , "." . . ' ." ';:o,:~t?¢'"":'. , ,.'.,., '~ r . ~-~ .<.?';.', ..... ., .... '.' ,, .,:' , '--.,,,,,,.":,.. ...... -...,"'..':,..., ~. K. I<REBfLL 067 ~t :;:t,'-" ,;~i (7. ~..-'.'~/ ,.., 17~?.. <..:;..".,'. ~.r:,'-.'; '.'t:';j '~F. K.~ Krebill ..... .?_ -. Area - ' '"~per~nten~ent -" .- . ..... ,. '' . .:5.. %' , .,, .~ . . -,, ;,. . ,. . . ~'%-. ~.,,, ~, ... .... t 5- .'- . ,,~.. t , · - Remarks CitLCK LIST FO?, '"-' · uumua~iy Yes No Is the permit fee attached ..................... ~ Is well to be located in a defined pool .............. ..K~E~K Is a registered survey plat attached ' · I-s well located proper distance from.property line ......... ~r,a< Is ',.:ell located proper distance from other wells .......... IS sufficient undedica-ted acreage available in this pool o 9. 10. 11. i2. 13. 14. 15. 16. 17. 18.. Is well'to be deviated ....................... Is operator the only affected party .................. Can permi-t be approved before ten-day wait ............. Does operator have a bond in force .................. Is a conservation order needed ................... Is a~xinistrative approval needed ................. Is conductor string provided ...................... Is enouoh cement used to circulate on conductor and surface .... Will cement~tie in surface and intermediate or production strings Will c~ment'cover all known producti_ve horizons ~.~ill surface casing protect fre~ water zones Will all casing give adequate safety in collapse, tension & burst 19. Does BOPE have sufficient pressure rating 20. Has DME~' approved Plan of Operation Additional Requirements'. 'l~ ,,~'~ ~ ~_ 4~~ Approval Recommended: Geol oa,~/: Enai n_ee. ri.nq: HWK ~/~ LCS~AD ~ Revised 11/17176