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178-003
THE STATE Alaska Oil and Gas 01 L SK l Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Mr. Chris Myers Field Superintendent Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 September 24, 2013 RE: No -Flow Verification SCANNED Trading Bay Unit G-17RD PTD 1780030 Dear Mr. Myers: On September 2, 2013 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no -flow test of Trading Bay Unit well G-17RD located on the Grayling Platform in Cook Inlet. The well is operated by Hilcorp Alaska, LLC (Hilcorp). A subsurface safety valve is not required to be installed in this well based on the no -flow test result. A fail- safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The AOGCC Inspector confirmed that the proper test equipment — as outlined in AOGCC Industry Guidance Bulletin 10-004 — was rigged up to Trading Bay Unit G-17RD. The no -flow test consisted of a series of flow and shut in periods. During the flow monitoring periods, no liquid production was observed and gas production — measured through the no -flow meter — was at rates less than 900 standard cubic feet per hour. The subsurface safety valve must be returned to service if Trading Bay Unit G-17RD demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Please retain a copy of this letter on the Grayling Platform. Sincerely, James B. Regg Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors r.svI. STATE OF ALASKA SSP 4 5 2013 ALAS OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate E Other 0 Irstalled ESP Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re-enter Suspended WeII❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development 0 Exploratory ❑ Stratigraphic❑ Service ❑ 178.003 3. Address: 3800 Centerpoint Drive, Suite 100 6. API Number: Anchorage, AK 99503 50-733-20161-01 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0017594 I Trading Bay Unit / G-17RD 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): McArthur River Field / Hemlock Oil and Middle Kenai G Oil 11. Present Well Condition Summary: Total Depth measured 12,140 feet Plugs measured N/A feet true vertical 10,233 feet Junk measured 11,636 feet Effective Depth measured 11,850 feet Packer measured N/A feet true vertical 9,960 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural 364' 26" 364' 364' Conductor 560' 17-3/4" 560' 560' Surface 3,978' 13-3/8" 3,978' 2,899' 3,090 psi 1,540 psi Intermediate Production 10,162' 9-5/8" 10,162' 8,374' 6,870 psi 4,760 psi Liner 2,485' 7" 12,140' 10,233' 8,160 psi 7,020 psi Perforation depth Measured depth See Schematic feet SCANNED SEP 2 52013 True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.3# / L-80 8,860' (MD) 7,135' (TVD) Packers and SSSV (type, measured and true vertical depth) N/A & N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 27 13 367 1120 110 Subsequent to operation: 27 16 346 68 72 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Developments Service ❑ Stratigraphic ❑ 16. Well Status after work: Oil Gas ❑ WDSP` ❑ Daily Report of Well Operations X GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 1312-443 Contact Ted Kramer Email tkramer Whilcorp.com Printed Name Ted Kramer Title Sr. Operations Engineer Signature 5✓'<'""` Phone (907) 777-8420 Date 9/4/2013 Form 10-404 Revised 10/2012 RBD S SEP — 9 21 Submit Original Only SCHEMATIC Ililmrp Alaska, LLC T( PBTD = 11,850' ETD = 12,140' Max angle = 58° @ 2526' McArthur River Field, TBU Well: G-17RD As Completed: 08/05/13 Casing Detail Size I WT Grade Top Btm Length 26" 2 8,868' Surf 364' 8,869' 17-3/4" Spiral Weld Surf 560' 8,911' 13-3/8" 61 J-55 Surf 3,978' (Top of Window) 9-5/8" 47 N -80/S-95 Surf 10,162' Feb -78 7" Li 29 N-80 9,655' 12,140' 2,485' Tubing: Apr -98 Open 11,200' 11,277' 9,352' 3-1/2" 9.3 L-80 Surf 8,860 8,860' JEWELRY DETAIL No Depth Item 1 31.38' 3-1/2" Hanger Assy. 2 8,868' Discharge Head 3 8,869' Pump Model #116 P18 - 2 sections 4 8,910' Pump Intake 5 8,911' Seals Model GSB3DB (2) 6 8,925' Top of Motor - Model # MSP1 7 8,947' Bottom of ESP (Anode) REVISED: 09/03/13 by JLL Perforation Record TOP (MD) BTM (MD) TOP (TVD) BTM (TVD) ZONE SPF DATE COMMENTS 4,006' 4,007' 2,914' 2,915' NA 4HPF Feb -78 Sqzd 4,114' 4,115' 2,975' 2,975' NA 4HPF Feb -78 Sqzd 11,197' 11,216' 9,349' 9,367' G-5 6HPF Apr -98 Open 11,200' 11,277' 9,352' 9,424' G-5 Pure 07/31/13 Open 11,252' 11,278' 9,400' 9,425' G-5 6HPF Apr -98 Open 11,375' 11,412' 9,515' 9,550' HB -1 6HPF Mar -98 Open 11,378' 11,408' 9,518' 9,546' HK -1 Pure 07/31/13 Open 11,382' 11,412' 9,522' 9,550' HB -1 4HPF Mar -78 Open 11,382' 111412' 9,522' 9,550' HB -1 4HPF Sep -78 Open 11,382' 11,412' 9,522' 9,550' HB -1 Mar -89 Open 11,382' 11,412' 9,522' 9,550' HB -1 6HPF Mar -91 Open 11,430' 11,450' 9,567' 9,585' HB -2 6HPF Mar -98 Open 11,432' 11,512' 9,568' 9,643' HB -2 4HPF Mar -78 Open 11,432' 11,512' 9,568' 9,643' HB -2 4HPF Sep -78 Open 11,432' 11,512' 9,568' 9,643' HB -2 Mar -89 Open 11,432' 11,512' 9,568' 9,643' HB -2 6HPF Mar -91 Open 11,450' 11,512' 9,585' 9,643' HB -2 6HPF Mar -98 Open 11,522' 11,584' 9,653' 9,711 HK -3 Pure 07/31/13 Open 11,535' 11,570' 9,665' 9,697' HB -3 4HPF Mar -78 Open 11,535' 11,570' 9,665' 9,697' HB -3 4HPF Sep -78 Open 11,535' 11,570' 9,665' 9,697' HB -3 Mar -89 Open 11,535' 11,570' 9,665' 9,697' HB -3 6HPF Mar -91 Open 11,535' 11,569' 9,665' 9,697' HB -3 6HPF Oct -94 Open 11,621' 11,634' 9,745' 9,757' HK -4 Pure 07/31/13 Open REVISED: 09/03/13 by JLL • Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-17RD 50-733-20161-01 178-003 7/16/13 8/5/13 Daily Operations: 7/16/2013 -Tuesday Rigging up. 7/17/2013- Wednesday Pull BPV f/ tubing hanger (tubing static). Pump 100 bbls of 8.5# FIW down annulus. Open tubing & had slight blow. Install two way check. P/U 3-1/2" test joints & test equip. Begin testing BOP'S & related equipment with 3-1/2" & 4-1/2" pipe per AOGCC regulations. 7/18/2013 - Thursday Tested BOP's 250L/3000H, witness of test waived by Jim Regg, AOGCC. Finish BOP Test. Pull 2 way check valve and test plug. Mix and pump 40 bbl salt pill. R/U Pine. RIH w/wireline. RIH with gauge ring and CCL to 10,776' no restrictions. POOH with a -line, observed no overpull. RIH with chemical cutter. Correlated tubing collars/gas lift mandrel and packer. Spot chemical cutter at 10,730'. Fire chemical cutter. Cut made at 10,730'. POOH with chemical cutter. Cutter showed fired. R/U to circulate hole and clean hole. Circulating hole x 2 volumes. No signs of gas. 7/19/2013 - Friday Finish circulating hole clean. Stop circulating at 8:30, observed annulus, still flowing. Continue to circulate 45 minutes more. Back side static. R/U to pull tubing hanger. Pulled to 120-130K. Hanger came free and continued to pick up what looks like to the chemical cut at 10,730'. Break out tubing hanger and lay down. Continue POOH of control line and TRSSSV. Laying joints down in singles. POOH with 4 1/2" production string installing protectors and laying down in singles/ bundling with plastic covering. Recovered 4 gas lift mandrel of 11 so far. 216 jnts. pulled. 7/20/2013 - Saturday Finish POOH with 3 1/2" production string. Recovered 11 gas lift mandrels and 10,730' of tubing. PU/MU RIH with 5 3/4" overshot w/ 3 1/2" grapple and mill control, 4 3/4" bumper jar, 4 3/4" oil jar, 6 ea. 4 3/4" drill collars, 4 3/4" ACC Jar and 3 1/2" PH6 tubing. Tag liner top +/- 28' in on joint 300. Rotate pipe. Slack off. RIH. Tag/latch fish. Currently jarring on seals. 7/21/2013 -Sunday Hit jars 7 times and jarred seals free. 15" of seals. Circulate BU reversing. Small amount of gas to surface. Continue circulating out. POOH with overshot/jar assembly and seals. Continue to POOH. Lay down BHA. BHA recovered intact. Install wear bushing. Pick up packer milling BHA -5 3/4" milling shoe, 5 3/4" extension, top bushing, 2 ea. 41/4" Boot baskets, 4 3/4" bumper jar, 4 3/4" Oil Jar, 6 ea. 4 3/4" drill collars and 4 3/4" ACC jar. RIH w/BHA on 3 1/2" PH -6 tubing. Tag packer at 10753' drill pipe measurement. Rig up power swivel. Swivel torqueing up. Unable to rotate. Max out at 8300 ft/lbs. Work pipe up and down. Circulate bottoms up. Pull back to liner top. Wash down to top of packer. • Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-17RD 50-733-20161-01 178-003 7/16/13 8/5/13 Daily Operations: 7/22/2013 - Monday Pull up to top of 7" liner. Laying workstring down in singles. Attempt to wash down inside of 7" liner to make sure it is clean. Could not rotate. POOH with workstring and packer milling assembly. Ordered 4 3/4" OD Baker high torque mud motor to mill packer. Pumped 199 bbl tank to Trading Bay. Manifolded to Bingham pump on platform. Will use this pump to have 8 bpm flow rate. Moved transducer to capture pressure on flowline. Will pump directly to Trading Bay while milling packer. Cleared with Dan Marlowe/Platform manager/Trading Bay. POOH with packer milling assembly. OOH with packer milling BHA. Pick up new BHA -6 " OD milling shoe, washpipe ext., top bushing, double pin sub, Baker mud motor, double pin sub, 4 ea. 4.75 boot baskets, double box sub, 4.75 oil jar, 2 ea. 4.75 drill collars, 4.75 bumper jar, w ea. 4.75 drill collars, 4.75 ACC jar, x -over, 3.50 PH -6 tubing. Pump through BHA and confirm motor is working. 3 BPM/0 psi. RIH with new packer milling BHA. 7/23/2013 -Tuesday On bottom with packer milling assembly with mud motor to mill packer. Lined flow lines to water flood Bingham pump on platform and line up with Trading Bay. Begin circulating, establish parameters at 5bbl/6bbl/7bbl at different pressure rates. Begin milling, work BHA when motor stalls out. Complete milling packer in 2 1/2 hours. Pump 5 bbl Hi -Vis pill circulate BU long way. 72 viscosity. Switch flow to rig pump. Prepare to pick up 15 stands in singles and push packer mandrel to 11,653'. Downhole motor stalling with rig pump. Packer not moving downhole. Coordinate with production to pump with waterflood. Pump downhole with waterflood +/- 7.5 bpm at 2500 psi. Push packer assembly downhole. Continue to pump each joint downhole with waterflood and push packer assembly downhole. Ordered 20 joints 3 1/2" PH 6 workstring to get to 11,653. Pipe stuck at 11,221'. Work pipe free. Circulate bottoms up. Wash down to 11,252. Mix 20 pill will pump 10 bbl pill and continue to wash down. 7/24/2013 - Wednesday Continue to wash down and push packer mandrel and tail assembly. Using Bingham pump on platform to operate mud motor. Pumping 7 bpm. Washed to 11,204' had scale obstruction, worked motor and continue washing. Another tight spot at 11,536' continue to work motor and wash down. Washed down to 11,636', could not go any further. Circulate bottoms up long way. Begin POOH. Hole drag 60K over string weight dropping off to 40K hole drag after 6 joints out. Continue POOH. Lay down BHA. Pick up bit and 9 5/8 scraper. RIH. Tag liner top. Pick up. Rev x 2 bottoms up. 7/25/2013 - Thursday Finish POOH with 9 5/8" scraper. Land test plug and test BOPE. Annular test 250 low/1500 high. Pipe/blind 3000. Choke/Kill manifold 3000. Accumulator State 1700-1900-23 seconds/3200-127 seconds. Nitrogen bottles 2200-2200- 2150. Waived witness per Jim Regg. BOPE test good. Slip drill line. Repair rig. Slip/cut drill line. Made up bit, scraper, jars and 1 stand of drill collars. The weight of the BHA, including the stand of drill collars, was taken by the elevators. The BHA was then lowered in the hole. The bit bumped the wear bushing as the BHA was being lowered in the hole the elevators opened. The BHA was dropped in the hole. Waiting on jars. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date 11 End Date G-17RD 50-733-20161-01 1 178-003 7/16/13 1 8/5/13 Daily Operations: 7/26/2013 - Friday Waiting on jars as backup set is in the hole on dropped assembly. Make up 5 3/4 overshot (w/4.75 grapple), 4 3/4 oil jar, 4ea. drill collars, ACC jar. RIH. Washed down to top of fish. Tag fish at 11,402'. Engage fish. Begin jarring on fish while circulating at 3 bpm/1400 psi. BHA moving up the hole. POOH slowly. OOH with complete fish. 16 hours downtime after deducting planned scraper run. Will lay down drill collars and prep for 7" casing test. 7/27/2013 -Saturday Lay down in singles 4 3/4" drill collars and fishing BHA consisting of 5 3/4" OD overshot dressed with 4 3/4" grapple and control, 4 3/4" bumper jars/oil jars - (2) 4 3/4" OD drill collars. Fish BHA consist of; 6" OD bit, 5 3/4" OD overshot dressed with 4 3/4" grapple and control, 4 3/4" bumper jars/oil jars - (2) 4 3/4" OD drill collars - (1) 3 1/2 IF lift sub. PU/MU 7" 29# RTTS test packer, (1) 4 3/4" oil jar - (2) 4 3/4" Drill collars xover to work string. TIH to 9825' - 170' in 7" liner. Fill hole, line up chart recorder, pressure to 2500 psi on casing. Held 39 minutes. No leaks. Bleed off pressure, RD chart recorder and transducer. Release 7" 29# RTTS packer and POOH. OOH with RTTS. Packing elements missing from tool. Lay down BHA. RIH with jetted mule shoe. Tagged at 11,500'. Pick up w/40k overpull. Pulled free. Lay down 1 joint. Circulate hole. Will line up to platform water flood and pump to Trading Bay to clean hole. 7/28/2013 -Sunday Circulating well clean. Washing from 11,405 to 11,613' with rig pump. Fluid loss averaging 15 bph. Line up to Trading Bay, circulate well until clean. Getting back sludge. Finish pumping to Trading Bay. Clean pit. Pump out pit to Trading Bay. POOH to 2000'. 32 stands in hole. Waiting on production tubing and perforating equipment. 7/29/2013 - Monday Finish circulating well clean to Trading Bay, had fair amount of paraffin sludge over shell shaker. Kill string at 3000' in well closed in. Unload production tubing and perf guns from boat and stage on pipe rack. Coordinate delivery of ESP equipment. Coordinate personnel timing for perforating and running production string. Go over needs for 28' coated ID pipe with welder and tool pusher to raise or build riser for pipe rack skid. Work on rig floor remote panel for pump. Service rig. Clean possum belly. Personnel arrives to begin running perf. guns. 7/30/2013 -Tuesday Waiting on TCP and E -Line personnel, on weather hold. Hold JSA with rig crew and control room personnel. PU/MU TCP guns to workstring. Pick up TCP guns, disconnect and RA sub. RIH on 3 1/2" PH -6 workstring. RIH.176 stands plus single - put top shot at +/-11148 per pipe talley. Rig up wireline. RA tag @ 10,992'. Pick up 22' to 10,970+/- Correlate guns on depth. i Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-17RD 50-733-20161-01 1 178-003 1 7/16/13 1 8/5/13 Daily Operations: 7/31/2013 - Wednesday Reviewed and received confirmation of log correlation from reservoir. POOH with E -line. Rig down E -line. Install pump in sub and safety valve. Fill hole. Drop 5/8" ball. Test circulation flow path to 500 psi 2 times. Pressure up to 2500 psi. Surface seismic sensor shows guns fired. Pick up 10 stands above perfs. Open annulus and monitor well 1 hour. No flow. POOH laying down in singles. Crankcase on rig broke. Well shut in and static. Repair crankcase. Rig back up and running. POOH laying down singles. Hole taking 22 bbls to fill. 08/01/2013 -Thursday POOH with perf. guns. Begin laying down perf. guns. All guns OOH all shots fired. Run 14 stands 3 1/2 workstring from derrick into hole. POOH laying down in singles. RU for BOPE test. Pull wear bushing, install test plug & assembly to begin testing bop's. Standby for Jeff Jones with AOGCC to witness bop testing. Test bop's & related equipment per AOGCC regulations with Jeff Jones (AOGCC Rep.) visually inspecting & witnessing test. Test vbr pipe rams, blind rams, kill line, choke line & manifold, (2) tiw valves, (1) ibop valve all to 250 psi low & 3000 psi high. Test Hydril to 250 low & 1500 psi high. Perform Koomey draw down. Initial psi = 3200, draw down pressure = 1700 psi, 200 psi attained @ 18 sec., full pressure @ 128 sec. Test gas (4) gas monitors with LEL & H2S test gas. All test were witnessed by Jeff Jones with AOGCC. Break & lay down test plug & assembly. Install wear bushing & prepare to P/U 3-1/2" RTS -8 production tubing. P/U 3-1/2" 9.3# RTS -8 production tubing & RIH with tubing to rack back in derrick. 08/02/2013 - Friday Continue P/U & RIH with 3 1/2" 9.3# RTS -8 production string to 9000'. Total of 285 jts. picked up. POOH with 285 jts. of 3- 1/2" 9.3# RTS -8 production tubing racking tubing in derrick. Pull wear bushing, clean rig floor & catwalk in preparation of picking up ESP. Spot flat pack spools, hang sheaves in derrick, R/U ESP equipment. Spot ESP on catwalk, wire up electric/hydraulic motor for cable reel with platform electrician. P/U & RIH with ESP assembly. Total of 78 bbls of FIW lost to formation in last 24 hrs. 08/03/2013 - Saturday P/U ESP & motor assembly with jewelry. Surface test ESP. RIH with 172 joints of 3-1/2" 9.3# RTS -8 production tubing from derrick to 5465', installing cannon clamps on flatpack & electric umbilical ESP line. Move second electric umbilical ESP cord reel to pipe rack, perform intermediate splice & test line. RIH with 196 jts of 3-1/2" 9.3# RTS -8 tubing installing cannon clamps on flat pack & electric umbilical ESP cord to 6221'. Hang off block & begin replacing brake bands with new pads. 130 bbls. In 24 hours. 0 E Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-17RD 50-733-20161-01 1 178-003 7/16/13 1 8/5/13 Daily Operations: 08/04/2013 -Sunday Change out brake bands & pads on rig draw works. RIH with 3-1/2" 9.3# RTS -8 production tubing from derrick, banding flat pack cable & ESP umbilical cord to tubing. RIH with 3-1/2" 9.3# RTS -8 production tubing, banding flat pack cable & ESP umbilical cord to tubing. Run total of 283 joints with BHA in hole. Installed total of 179 collar clamps & (3) 1-1/4" bands on pressure sub. Install tubing hanger & make final tie in to tubing hanger with umbilical cord & flat pack control line. R/D sheaves out of derrick. Test tubing hanger voids on both sides to 5000 psi & verify with company rep. tubing p/u wt = 110k, s/o wt = 93k. Land out tubing hanger setting end of ESP @ 8947.17'. Back out &L/D landing joint. Run in lock down pins with well head tech. R/D tongs & clear off rig floor. Isolate Koomey bottles & bleed down manifold & bop lines. N/D drip pan, Hydril, pipe & blind rams, & 11" riser w/mud cross. Lay out all bop equipment on deck with crane & secure. Dress tubing head w/ well head tech. Install 11" 5m x 4-1/16" 5m adaptor head with ESP cable port & torque down same. Install 4-1/16" production tree to adaptor head & torque down. Test tree void to 5000 psi for 15 minutes on both side & verify good test with company rep. Install two way check & test tree to 5000 psi. Assist production in hooking up flow line & control lines to G-17RD well in preparation in powering ESP up & bringing well on line. 08/05/2013 - Monday Assist production in bringing G-17RD well online. Ill • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg `'(( 1 c ''7/13 DATE: 9/3/2013 P. I. Supervisor FROM: Bob Noble SUBJECT: No-Flow Test Petroleum Inspector Hilcorp Alaska LLC TBU Grayling G-17RD PTD 178-003 9/2/13: I traveled to Hilcorp's Grayling platform. On arrival I met with Hilcorp platform Lead operator Zack Rolph. We discussed the No-Flow. Zack said that he had the well flowing to atmosphere for 32 hours. They had to hook up the no-flow gauge and we began the test. The test results are as follows: Time Pressure Status Flow Rate Remarks (psi) (scfh) 0800 0 S/I well 0 0915 1 Open well 15 Bled to 0 psi; 0 scfh in 5 min 0930 0 S/I well 0 1015 0 Open well 11 Bled to 0 psi; 0 scfh in 4 min 1045 0 S/I 0 1125 0 Open well 8 Bled to 0 psi, 0 scfh in 3 min Pressures —tubing pressure Flow Rate — standard cubic feet per hour (scfh) I removed hose from no-flow gauge and could not hear a whisper or feel slight flow on bare skin. I put finger over hose and didn't feel it pressuring up. Attachments: none T 2013-0902_No-Flow_TBU_G-17RD_bn.docx ■ r • • w . \ �� �� , ., THE STATE Alaska Oil and Gas �, �� ° ALAS L'�l 1 Conservation Commission " GOVERNOR SEAN PARNELL 333 West Seventh Avenue T Anchorage, Alaska 99501 -3572 0 FALAS �� S CANNED JAN q Main: 907.279.1433 2013 Fax: 907.276.7542 i Ted Kramer Senior Operations Engineer Hilcorp Alaska, LLC d 0 3800 Centerpoint Drive, Suite 100 i Z Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil and Middle Kenai G Oil Pool, Trading Bay Unit G -17RD Sundry Number: 312 -443 Dear Mr. Kramer: 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, , Cathy . Foerster Chair DATED this/, day of November, 2012. Encl. 4 STATE OF ALASKA 14141041 m E I D , ALASKA OIL AND GAS CONSERVATION COMMISSION NQi s I�� APPLICATION FOR SUNDRY APPROVALS A ®GCC 20 MC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pod ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate El • Pull Tubing ❑ • Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. Install ESP D. 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. Hilcorp Alaska, LLC Exploratory ❑ Development p • 178 -003 • 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number. Anchorage, AK 99503 50- 733 - 20161 -01 • 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? 20 AAC 25.055 (a) ' Will planned perforations require a spacing exception? Yes ❑ No El • Trading Bay Unit G -17RD - 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0017594 • McArthur River Field / Hemlock Oil and Middle Kenai G Oil . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12,140' • 10,233' 11,850' . 9,960' N/A N/A Casing Length Size MD TVD Burst Collapse • Structural 364' 26" 364' 364' Conductor 560' 17 -3/4" 560' 560' Surface 3,978' 13 -3/8" 3,978' 2,899' 3,090 psi 1,540 psi Intermediate Production 10,162' 9 -5/8" 10,162' 8,374' 6,870 psi 4,760 psi Liner 2,485' 7" 12,140' 10,233 8,160 psi 7,020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 4 -1/2" 12.6# N -80 Butt. 327' 3 -1/2" 9.3# N -80 Butt. 10,841' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker Model "F" Perm Packer and 3 -1/2" Halliburton "LXA" TRSSSV Baker Model "F" Packer 10,760' (MD) 8,941' (TVD) and TRSSSV 327' (MD) 327' (TVD) 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch p Exploratory ❑ Stratigraphic ❑ Development p • Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12/23/2012 Oil 0 Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ted Kramer Email tkramert7a.hilcorp.com Printed Name Ted Kramer Title Sr. Operations Engineer Signature � . '...c------ " Phone 907- 777 -8420 Date 11/26/2012 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 12- v cis a Plug Integrity ❑ BOP Test m Mechanical Integrity Test ❑ Location Clearance ❑ Other: . Bop 7 - $t 3 fs- Spacing Exception Required? Yes ❑ No d Subsequent Form Required: /0 — 4 D `J APPROVED BY Approved by: (a, / COMMISSIONER THE COMMISSION ■ Date: e_ Submit Form and 4 , 0 Rn 1 0G til t 12) Approved applicat ion i / f 12 months from the date of approval. A chment iicate A /(� /E5 valid /1 , ,� ��t � 11 • • Well Work Prognosis Well: G -17RD Hilcorp Alaska, LLC Application Date: 11 -26 -12 Well Name: G -17RD API Number: 50- 733 - 20161 -01 Current Status: Oil Producer Leg: Leg #4 Slot # 23(SW corner) Estimated Start Date: December 23, 2012 Rig: Williams Rig 404 Reg. Approval Req'd: 10 -403 Date 10-403 submitted: 11/26/12 Regulatory Contact: Juanita Lovett 777 -8332 Permit to Drill Number: 178 -003 First Call Engineer: Ted Kramer (907) 777 -8420 (0) (985) 867 -0665 (M) Second CaII Engineer: Mike Dunn (907) 777 -8382 (Office) (907) 351 -4191 (M) AFE Number: 1221775 Budgeted Cost: Pressures: Bottom Hole Pressure (BHP); Maximum Potential Surface Pressure (MPSP) Current BHP: 1,301 psi @ 9,549' TVD From 10/2011 Gas Lift Survey Max. Expected BHP: 3,863 psi @ 9,549' TVD* MPSP: 1,600 psi** "based on 2009 shut -in pressure survey. Note: This well has been a producer with no nearby injector support. * *Using 0.1 psi /ft. of True Vertical Depth from deepest known gas © 4775' TVD by March /1978 Neutron Density log. Status: Active producer. Making 300 bfpd, 30 bopd, taking 2.8 MMscfpd lift gas. Objective: Pull 3 -1/2" GL completion, re- perforate G -zone and HB, Run ESP. Rig Scope: 1. SL: scale check, dummy run as necessary to cut tubing above packer. 2. Cut tubing above seal assembly. Circulate FIW around. BAP ¢r5 / fo 36 5 l 3. ND Well head, NU BOP. Test same (Note: Notify AOGCC 48 hours in advance to wit ness). 4. Pull hanger, SSSV, and tubing string from cut. LD same. Norm check, send to shore. 5. Overshot and grab seal assembly stub looking up. POOH. LD seal assembly. 6. PU burning shoe, mill, retrieve packer. 7. Make 8 -1/2" bit /scraper run to PBD and CBU with clean FIW. 8. Run test packer to just above top pert, test backside to 2,500 psi. POOH. ~ - 9. Perforate G -zone and re -perf GZ and HB with TC guns, per Perf Log. 10. Run ESP, 3 -1/2" tubing ESP sized for 3,000 bfpd (BWS- 00063). 11. ND BOP, NU Well Tree and Test same. 12. Turn well back to Production. I 11 ki vLi 1 Aiv A-o G-lec . • • II Well Work Prognosis Well: G -17RD Hi!carp Alaska, LLC Application Date: 11 -26 -12 As -built (Old) Wellbore Schematic SIZE %IT GRADE TOP BTM LENGTH 1 26" Surf 364' L 3 1 17- 3 /4"Spiral Weld Surf 560' 13- 3/8 "61 J-55 Surf 3978" (TopofWmdow) 4 9 -5 %S" 47 >I -SO S-9 5 Surf 10,162' 5 7 "Liner 29 N -80 9655' 12,140' 2485' Tubing: 3 -1 _" 93 N -SO Butt SSSV 10,841' i 6 SSSV 327' 1 7 J JEWELRY DETAIL NO. Depth Ws 1 8 1. 36' 4- U7 " EVE TBGHangar 9 2. 327' 4-1/2" 12.61b ft Butt Dg 3. 327' 3 -1/2" HES "LXA" TRSSSV (2.813 "ID) 4.. 2612' 3 -1 Q Tt*t to 2 alla D& 10 5:15. Magaz 3- 1!2 " GEM' sat 11 2612%5245%6606%7391%7856%8321%8815', 9280',9744',10210',10706' TOC @ 10030» i 12 16. 10,756' Locator SealAww/15'sealbore extension 13 17. 10,760' Baker Nlo del FPerrnanentPacker (4 "ID) 18. 10,764' Seal Bore Extension 15 w crossover . 14 19. 10,808' Baker - X° nipple profile 20. 10,841' WEREG 15 .X Perforation Record TOP BIM ZONE SPF DATE COMMENTS . 4 16 4006 4007 NA 4HPF 2 78 4114 4115 NA 4HPF 2 ?8 C ye I7 11382 11412 HB-1 4HPF 3.78 Open t 8 11432 11512 HB-2 4HPF 3.18 Open 20 11535 11570 HB-3 4HPF 3'78 Open 11382 11412 HB-1 4HPF 9178 Open 11432 11512 HB-2 4HPF 9 Open 0 peds 11535 11570 HB-3 4HPF 9 Open 11382 11412 HB-1 3159 Open 11432 11512 HB-2 3 Open H33 11535 11570 HB-3 3,89 Open 11382 11412 HB-1 6HPF 3 91 Open HB 11432 11512 HB-2 6HPF 391 Open 11535 11570 HB-3 6HPF 391 Open 11535 11569 HB-3 6HPF 1094 Open 11522 11550 HB-3 6HPF 398 Open 11375 11412 HB-1 6HPF 398 Open 1LUC 11450 11512 HB-2 6HPF 3:98 Open 99 11430 11450 HB 6HPF 398 Open 11197 11216 G -5 611PF 498 Open 11252 11278 G -5 6HPF 498 Open PBID = unti o ta= 12,140' Max angle= 58` @ 2526' • • Well Work Prognosis Well: G -17RD Hilcorp Alaska, LLC Application Date: 11 -26 -12 Proposed (New) Wellbore Schematic Casing Detail - Sint WT Grade Top Elm Length ,'I - 26' Surf 364' 550 17 -3/4' Sprat Weld Surf ' 13 -3/8 61 5-55 Surf 3,975' {Top of Wind** 9-5/8' 47 #40/5-95 . Surf 10.162' 'Miner 29 #480 9,655' 12.140' 2485' Tubing: `--' --. 3 -3/2' 93 N-30 Sure SSSV 10,841' 4-1/2' 12.6 N-SO Butt Su rf 5555 327' JEWELRY DETAI s No Depth Item i , I 40.9' 3 -112' Manq r.Ass1. 75 2 38715 Mead Bolt On D itch sn e 5 3 18716 Pump SIB D58CCN - 6 sections 18847 Pu roe Make 5 18850 Protectors - Maximus 1SBP8 -UT {21 TOO @ IC,03C' 6 18856 Top of Motor SO 456,18, 4183 Maximus - 2 motors 7 18933 Bottom of ESP Perforation Record TOP Uhl TOP BTM (MD) (MD: TVD} {T�pi ZONE SPF DATE COMMENTS 4,006' 4,007 2114' 2,91.5' NA 411PF Feb-75 Seed 4,114' 4,115 2,975' 2,975' NA 411Pf Feb-73 Sgzd 11,126 11,132 9,283 9 ,289' G-4 P urn Future Proposed 11497' 11,215 9,349 9,567' 6-5 611Pf Apr-98 Open L- ,] 11200' 11,215 9,352 9366'. 0 -5 P Future Proposed 11 ,234 11,245 9,384 9,394' 0 -5 Pure Future Proposed 11.252' 11,278 9,400" 9425' 6-5 61 41. Open 11,252 11 ,278 9,400 9,425 G -5 Pu re Fat re Proposed 11.375' 11412' 9,315 9.550' eat 611Pf Ma-93 Open 53 Pe rfs 11,378` 11,408 9.518 9,549 11K -1 Pure Fata'e Proposed 0 -5 Pe rfs 11,382' 1.1,412 9322' 9 ,550' Mal 41iPf Mar -78 Open 11,382' 11,412 9322' 9350 Mal 411Pf Sep- ?3 Open 114-1 Perfs 11,382' 11.412 9,522 9350' M61 Mar-89 Open M5-1 11382' 11412 9522' 9350' 119-1 555Pf Mar-91 Open 11,430' 11430 9,597 9585' #6-2 SMPF Mar-93 Open I 115-2 11432' 11,312 9.565 9,543' M9-2 4MPF Mar-73 Open = 11432' 11,512 9.563 9,643' #8-2 41.1Pf Sep-78 Open m #9.3 11432' 11.512 3553 9.443' 95-2 Mar-119 Open Mr -3 11.432' 11,512 3 5'3 9,443' #9-2 6MPf Mar 91 Open 11450' 11,512 9.535 9643' 96.2 311 P Mar-93 Open �� 11,425'&iTOf 11,522' 115 M 50 3_53 9,597' ai 69FF Mar-98 Open 3/12/93 11522 11,553 9,682 M4 -3 Pre Fnre a-c pried 11335' 11370 5 555 9,697' 599-3 411PF Mar-78 Open 11535' 11.570 9555 9497' 558-3 411PF Sep-711 Open �, _ 1111 ����1111 7'T7711 11.535' 11370 3 555 3.697' #9-3 Mar-49 Open aetebl.R} "F`war,-1�1'{Q' 11335' 11,57C' 9555 5697' 119-3 6t9Pf Mar-91 Open Max angle= 1:25' -6' 11335' 11,59' 9 555 9397' 99-3 SMP' Ott94 Open • I Well Work Prognosis Well: G -17RD Hilrnrp Alaska, LLC Application Date: 11 -26 -12 Williams Workover Rig • ' Grayling Platform BOP 2012 III:II I_III_III I III_III Weatherford Rental 8OP Width 4.16' 3.74' Weight 13,1009 Shaffer 13 5/8 5M Shaffer LWS , Total BOP height above - 1358 5M LWS 1358 5M drill deck dimensions © 9.46' min Length 7.73' 3.00' 11.48' max Width across body 2.72' Width across flanged — — _... outlets 4.00' = Weight 9500lbs 9.00' Mud Cross 1 II! I11I11 ill 28501bs w/ valves iI 1.74' ` III Iil 111111 I11 Riser above drill deck III I I I This number will vary from well to well 1.00' to 3.00' 8 Drill Deck • 13 5/8 5M Riser 85001bs 1500' yth III III III , 1 Spacer Spool 135/85M X 135/85M '1 1.95' 18001bs III . lftt III I I I Crossover Spool 135/85M X115M 1800lbs 2.83' III II Top of Wellhead • • Well Work Prognosis Well: G -17RD Hilcorp Alaska, LLC Application Date: 11 -26 -12 Attachment #1 Hilcorp Alaska LLC. BOP Test Procedure: Williams Rig 404, Grayling WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND /NU. Confirm that well is static. Initial Test (i.e. Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2 -way check in hanger. 3) Space out test joint so end of tubing (EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If BPV profile is eroded and /or corroded and BPV cannot be set with tree on, Profile and /or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. Conduct Rolling Test. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV. As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2 -way valve, or prepare lift- threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2 -way check valve by hand, or MU landing (test) joint to lift- threads d) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test, notify office via e-mail that neither profile will allow for a test of the BOP. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path, test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down -hole and not leaking anywhere at surface.) • Well Work Prognosis Well: G -17RD Hilcorp Alaska, LLC Application Date: 11 -26 -12 d) Hold a constant pressure on the equipment and monitor the fluid /pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f) Record and report this test with notes in the remarks column that the tubing hanger /BPV profile wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re -land hanger (or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests (i.e. Test Plug can be set in the Tubing -head) 1) Remove Wear bushing. a) Use inverted test plug to pull wear busing. MU to 1 jt. of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same, and RIH on 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Break joint off test plug and pull up to space the bottom of tool joint above blind rams. 4) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE (after 2-way (afte ay check or test plug is set) 1) Fill stack with rig pump and install chart recorder on the stack side of the pump manifold. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder. 3) Referencing the attached schematics test rams and valves as follows. a) Close C -1 (inside gate valve on choke side of mud cross) and close the annular preventer. Pressure test to 200 psi for 5 minutes and 1,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open annular. b) Close Pipe Rams. Test to 200 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open pipe rams. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack, test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 200 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open rams. d) Open C -1. Flow through the choke manifold and purge air. Test the choke manifold starting with the outer most valves, to 250 psi low and 3,000 psi high, for 5 minutes each, as follows: (Valve numbers are in reference to Diagram B) i) Valves 1, 2, 10. After test, open same. i i * H Well Work Prognosis Well: G -17RD Hilcorp Alaska, LLC Application Date: 11 -26 -12 ii) Valves, 3, 4, 9. After test, open valves 3 & 4. Leave 9 closed. iii) Valves 5, 6, 9. After test, open valves 5 & 6, leave 9 closed. iv) Valves, 7, 8, 9. After test, open all valves. e) Close C -2. This is the HCR (the hydraulic controlled remote) valve just outside C -1 on choke side of mud cross. Test to 250 psi low and 3,000 psi high. After test, open HCR, close C -1. f) Blind Rams. Make sure test joint is above the blind rams. Close blind rams. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. Bleed down pressure. g) Bleed off all pressure. Line up pumps to pump down tubing. h) Test K -1, K -2, and K -3 on the kill (pump -in) side by pressuring up on tubing. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. i) Test floor valves TIW (or Lower Kelly Valve) and IBOP. STANDARD TEST PROCEDURE OF CLOSING UNIT (ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure ". It should be +/- 3,000 psi. 3) Close Annular Preventer, the Pipe Rams, and HCR. Close 2 set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi "). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre- charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually +/- 30 seconds. 8) Once 200 psi pressure build is reached, turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut -off after the pressure to builds back to original pressure ( +/- 3,000 psi). Note: Make sure the electric pump is turned to "Auto ", not "Manual" so the pumps will kick -off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves, for correct operating position 3) Fill out the AOGCC BOPE Test Form (10 -424) in Excel Format and e-mail to AOGCC and Juanita Lovett. • Well Work Prognosis Well: G -17RD Hileorp Alaska, LLC Application Date: 11 -26 -12 Diagram A -1: Grayling BOP stack and Riser Arrangement — Typical for Single Completion W Illlams Workover Rig Grayling Platform BOP 2012 L 1 • Ii 1 I I WeethMOrd Rental SOP Width 4.16' 3 74' Shaffer 13 603 6M ltd rtfi rtfi rtfi t T6 I — f 3113536/8.8 r LWS 136/86MLWS 1I dimensions Length 7.73' — _ 3. 00' Width across body 2.72' Width across flanged . = outlets 4.00' = = • , _ III 1 111 Tv � o p' 1N 1•110, -101101 +!al!' l (y/M� 1' � ���� 1.74' K-3 K-2 K-1 11 11 1 s C -1 -1 0 C- 2'HCR' • Mud Cross Riser above drill deck This number will vary from well to well 1 00' to 3.00' Dnll Deck 13 6/8 6M Riser 80001bs 135/85MX 15.00' 3 1/8 5M EFO i iii • III Ill Spacer Spool 13 6/8 6M X13 6/8 6M 1.95 1800lbs Itt II • I Crossover Spool 136/86M X1165 18001bs 2.83' iI III Top of Wellhead • • • Well Work Prognosis Well: G -17RD Hilcorp Alaska, LLC Application Date: 11 -26 -12 Diagram A -2: Grayling BOP stack and Riser Arrangement — Typical for Dual Completion Williams Workover Rig Grayling Platform BOP 2012 Sheffer SL 135/8 6M 144' 135/85/8 Spacer spool 2.00' }}�� n I• 1111 III Width 4.16'i 3.74' Shatter 13 6/8684 iii iii Iii I I Shaffer LWS _ 13 5/8 684 LWS 13 6/8 6/8 dimensions Length ].]3' Width across body 2.72' A 001 Width across flanged cutlets 4.00• .— * *- ran �� u � �1 I .)' `_ • l I r .4 Vr ' ' - I /.4 1 ,1 , 1.74' K ' K-2 K1 "' f ' • C -1 C- 2'HCR Mud Cross Riser is number above will drill d vary k from well to well 1 00' to 3.00' Doll Deck 13 6/8 6M Riser 86001bs 135/85MX 1500, 3 1/8 5M EFO iI I r II III Spacer Spool 135/86M X 136/85M 1.95' 18001bs III III III III Crossover Spool 13 6/8 6M X116M 18001bs 283' III III Top of Wellhead • 0 Well Work Prognosis Well: G -17RD Hilcorp Alaska, LLC Application Date: 11 -26 -12 Diagram B: Grayling Choke Manifold To Gas Buster All National type To Panic line 2 1/16 5M 1502 Union ball valves IBM III*il 1 s \i/ 4 11" ( ft L . 4. '.'.1.: III III I' Chokes are 90 degrees off • in drawing in order to show 1 detail 1, 1 : l i 1. _I Ii 1 ;1t 16116I. :I III - - Swaco \ Ii_ II. III III 1.1111/ IIII I .H Ills From Bop Choke Line 2 1/16 5M Unibolt Flange Valve Type #1 National Ball Valve B3260, 3'A" Ball port, 6000psi working pressure #2 National Ball Valve B3260, 3'/4" Ball port, 6000psi working pressure #3 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #4 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #5 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #6 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #7 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #8 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #9 National Ball Valve B3260, 3'/4" Ball port, 6000psi working pressure #10 National Ball Valve B1560, 1 'A" Ball port, 6000psi working pressure 1 Ii FLUID FLOW DGRAM NORMAL OPERATIONS CIRCULATING DOWN CASING, UP TUBING REVERSE CIRCULATING" • STANDPIPE PANIC LINE 1. ❑ Q • I ca I ca I ir STRIP PER o ° • MAD • BOP ■ I•MIUAL AUTO rATC Z 10 STACK ∎ CHOKE CNONE OW CQ IA • ' °00 C C Q I -IIL.JJII1 MUD I q I PUMP Y _,,, :..::1 , Da PUMP C i MANIFOLD , VALVE LP ;+L; Ng SUCTION e USTER LINE /1, • FLUID TPNKiPIT D CD I'D 'C _ G1 O O I" -, • V 0 0 O v et CfQ ( . 1 . 0 N H F" v N 01 N N 1 I WILLIAMS RIG #404 FLUID FLOW DIAGRAM NORMAL OPERATIONS CIRCULATING DOWN TUBING, UP CASING ANNULAS THE LONG WAY" STANDPIPE 1 PANIC LINE IE 0 • .. I I _ I I y i STP.IPPE P. t .:,, .., n Fr.D BOP E,li MANUAL ` AUTO KATC 0 Z STACK '- NOKE CNO KE ► DO CO C C o0 0 1 -1121 MUD 1 =1 Ih PIJMP PUMP MANIFOLD VALVE LP GAS *6 SO: TI ON I UBTER\ LINE /1 • ■ Ita C C -4 FLUID TM1k.PIT (D (D _ rt G p O I'' - 0 V �v 0 o v r (IQ 3 0 N N . N VI N 01 N N / • • McArthur River Field, TBU Well: G -17RD " "Alaska, LLC As Completed: 4/12/98 SIZE WT GRADE TOP BTM LENGTH 1 26" Surf 364' 2 17 -3/4" Spiral Weld Surf 560' 13-3/8" 61 J -55 Surf 3978 Top p of Window) ®3 9 -5/8" 47 N- 80/S -95 Surf 10,162' 7 "Liner 29 N -80 9655' 12,140' 2485' i 5 Tubing: 3 -1/2" 9.3 N -80 Butt SSSV 10,841' J 6 4 -1/2" 12.6 N -80 Butt Surf SSSV 327' L 1 7 JEWELRY DETAIL NO. Depth Item . 8 1. 36' 4 -1/2" EUE TBG Hangar 9 2. 327' 4 -1/2" 12.61b /ft Butt Tbg 3. 327' 3 -1/2" HES "LXA" TRSSSV (2.813 "ID) l0 4. 2612' 3 -1/2" 9.2 lb /ft Butt Tbg. L 5. -15. Macco 3 -1/2" GLM's at J 11 , 2612', 5245', 6606', 7391', 7856', 8321', 8815', — — 9280', 9744', 10210', 10706' TOC @ 10030' - 12 16. 10,756' Locator Seal Assy w /15' seal bore extension 13 17. 10,760' Baker Model F Permanent Packer (4" ID) 18. 10,764' Seal Bore Extension 15' w /crossover i 14 19. 10,808' Baker "X" nipple profile 20. 10,841' WLREG L -I 15 Perforation Record TOP BTM ZONE SPF DATE COMMENTS 16 4006 4007 NA 4HPF 2/78 Sqzd 141 17 4114 4115 NA 4HPF 2/78 Sqzd 11382 11412 HB -1 4HPF 3/78 Open 18 11432 11512 HB -2 4HPF 3/78 Open 20 11535 11570 HB -3 4HPF 3/78 Open 11382 11412 HB -1 4HPF 9/78 Open 11432 11512 HB -2 4HPF 9/78 Open G -5 Perfs 11535 11570 HB -3 4HPF 9/78 Open 11382 11412 HB -1 3/89 Open 11432 11512 HB -2 3/89 Open HB -1 11535 11570 HB -3 3/89 Open 11382 11412 HB -1 6HPF 3/91 Open HB -2 11432 11512 HB -2 6HPF 3/91 Open HB-3 11535 11570 HB -3 6HPF 3/91 Open – 11535 11569 HB -3 6HPF 10/94 Open 11522 11550 HB -3 6HPF 3/98 Open 11375 11412 HB -1 6HPF 3/98 Open z_t 11,826' 11450 11512 HB -2 6HPF 3/98 Open Est TOF 11430 11450 HB -2 6HPF 3/98 Open 3/12/98 11197 11216 G -5 6HPF 4/98 Open 11252 11278 0-5 6HPF 4/98 Open PBTD = 11,850' ETD = 12,140' Max angle = 58° @ 2526' G -17RD Schematic 04.12.98 REVISED: 11/8/2012 by MDD ' r • • McArthur River Field, TBU PROPOSED Well: G -17RD Hilcorp Alaska, LLC As Completed: 4/12/98 Casing Detail 1 Size WT Grade Top Btm Length 26" Surf 364' 17-3/4" Spiral Weld Surf 560' L L B 13-3/8" 61 1-55 Surf 3,978' (Top of Window) 9 -5/8" 47 N- 80/S -95 Surf 10,162' 7 "Liner 29 N -80 9,655' 12,140' 2,485' Tubing: Z , 3 -1/2" 9.3 N -80 Butt SSSV 10,841' 4 -1/2" 12.6 N -80 Butt Surf SSSV 327' JEWELRY DETAIL 2 3 No Depth Item 4 1 40.9' 3 -1/2" Hanger Assy. 5 L , 2 ±8715 Head Bolt On Discharge 6 3 ±8716 Pump SLB D5800N - 6 sections 4 ±8847 Pump Intake 7 - - 5 ±8850 Protectors - Maximus LSBPB -UT (2) TOC @ 10,030' 6 8866 Top of Motor SLB 456, 18, 4183 Maximus - 2 motors 7 ±8933 Bottom of ESP Perforation Record TOP BTM TOP BTM ZONE SPF DATE COMMENTS (MD) (MD) (TVD) (TVD) 4,006' 4,007' 2,914' 2,915' NA 4HPF Feb -78 Sqzd 4,114' 4,115' 2,975' 2,975' NA 4HPF Feb -78 Sqzd 11,126' 11,132' 9,283' 9,289' G -4 Pure Future Proposed 11,197' 11,216' 9,349' 9,367' G -5 6HPF Apr -98 Open L 11,200' 11,215' 9,352' 9,366' G -5 Pure Future Proposed 11,234' 11,245' 9,384' 9,394' G -5 Pure Future Proposed 11,252' 11,278' 9,400' 9,425' G -5 6HPF Apr -98 Open 11,252' 11,278' 9,400' 9,425' G -5 Pure Future Proposed 11,375' 11,412' 9,515' 9,550' HB -1 6HPF Mar -98 Open - G -4 Perfs 11,378' 11,408' 9,518' 9,546' HK -1 Pure Future Proposed G -5 Perfs 11,382' 11,412' 9,522' 9,550' HB -1 4HPF Mar -78 Open 11,382' 11,412' 9,522' 9,550' HB -1 4HPF Sep -78 Open - HK -1 Perfs 11,382' 11,412' 9,522' 9,550' HB -1 Mar -89 Open = 11,382' 11,412' 9,522' 9,550' HB -1 6HPF Mar -91 Open - HB-1 11,430' 11,450' 9,567' 9,585' HB -2 6HPF Mar -98 Open = HB-2 11,432' 11,512' 9,568' 9,643' HB -2 4HPF Mar -78 Open 11,432' 11,512' 9,568' 9,643' HB -2 4HPF Sep -78 Open HB -3 11,432' 11,512' 9,568' 9,643' HB -2 Mar -89 Open HK -3 11,432' 11,512' 9,568' 9,643' HB -2 6HPF Mar -91 Open - 11,450' 11,512' 9,585' 9,643' HB -2 6HPF Mar -98 Open 11,826' EstTOF 11,522' 11,550' 9,653' 9,697' HB -3 6HPF Mar -98 Open 3/12/98 11,522' 11,553' 9,653' 9,682' HK -3 Pure Future Proposed A 11,535' 11,570' 9,665' 9,697' HB -3 4HPF Mar -78 Open 11,535' 11,570' 9,665' 9,697' HB -3 4HPF Sep -78 Open 11,535' 11,570' 9,665' 9,697' HB -3 Mar -89 Open PBTD = 11,850' ETD = 12,140' 11,535' 11,570' 9,665' 9,697' HB -3 6HPF Mar -91 Open Max angle = 58° @ 2526' 11,535' 11,569' 9,665' 9,697' HB -3 6HPF Oct -94 Open REVISED: 11 -20 -2012 by JLL • • Ferguson, Victoria L (DOA) From: Ted Kramer [tkramer ©hilcorp.com] Sent: Wednesday, November 28, 2012 12:28 PM To: Ferguson, Victoria L (DOA) Subject: RE: TBU G -17RD (PTD 178 -003, Sundry 312 -443) Victoria, BOP Test Pressure will be 250psi low / 3,000 psi high. Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. O 907 - 777 -8420 C 985- 867 -0665 From: Ferguson, Victoria L (DOA) J mailto :victoria.fergusoraalaska.govl Sent: Wednesday, November 28, 2012 11:11 AM To: Ted Kramer Subject: TBU G -17RD (PTD 178 -003, Sundry 312 -443) What is your BOP test pressure? Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793 -1247 victoria.ferquson a(�alaska.gov 1 e e FRANK H. MURKOWSKI, GOVERNOR ALASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. T" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 July 25, 2006 Mr. Chris Myers Field Superintendent Unocal PO Box 196247 Anchorage, Alaska 99519 f)C~~~tJ, ,,' RE: No-Flow Verification Trading Bay Unit G-17RD, PTD 178-003 Dear Mr. Myers: On July 10,2006 an AOGCC Petroleum Inspector witnessed a "no flow test" at Unocal's Grayling platform, Trading Bay Unit Well G-17RD. The well was opened to atmosphere through flow measurement equipment with suitable range and accuracy and monitored. The well demonstrated no gas or fluid flow while open to atmosphere. Pressure increased to 15 psi during a 3-hour shut in monitoring period. The well demonstrated a peak flow rate of 300 standard cubic feet per hour when reopened to flow, decreasing to zero flow rate within 5 minutes. The subsurface safety valve may be removed from service in Well G-17RD based on this no-flow test result. Fail-safe automatic surface safety valve systems capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if the well demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Please retain a copy of this letter on the Grayling platform. Sincerely, ~\ ~'0 ~J ((i;W¿X\ b, \ \ t?4 c,' James B. Regg C \. { Petroleum Inspection Supervisor cc: Bob Fleckenstein .. , '" ' i STATE OF ALASKA I' ALAst. OIL AND GAS CONSERVATION COMMt -,ION REPORT OF SUNDRY WELL OPERATIONS F ~¡ f" ¡\"""" t '~J j""''' ~,: 'u oc.::.'d \ ~_{ ~'_)IJ 20 0 5 :; -. '\ PO Box 196247, Anchorage, AK 99519 '~,. . ,." "., '. ., :., i'~ ç,~ :';':,n¡;~ < n' StimulateU ,'.:Lq Othêr'td ': '~~Pßrforate WaiverD Time ExtensionD¡'~:"':: ::".i.; Re-enter Suspended Well 0 ,~) , SI¡ ~ 5. Permit to Drill Number: Exploratory 0 .1 Cß- I U~ . I '7<¡ !JO 3"'D Service 0 6. API Number: 50-733-20161-01 9. Well Name and Number: G-17RD 10. Field/Pool(s): McArthur River Field/Hemlock, G-Zone 1. Operations Abandon U Repair Well U Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator Union Oil Company of California Name: 3. Address: Plug Perforations U Perforate New Pool 0 Perforate 0 4. Current Well Class: Development 0 Stratigraphic 0 7. KB Elevation (ft): 103' RT to MSL 8. Property Designation: Grayling Platforms 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural Conductor Surface Intermediate Production Liner Perforation de:pth: measured 12,140' true vertical 10,217' feet feet Plugs (measured) n/a Junk (measured) n/a measured 11,950' true vertical 10,062' C'" C' (,\\ ~,,' ¡-.. i ih:: t"\ (: i:ï:ï) f1 "'\ cì n n ") 'ì)\;( â'ì:.~ ",f\,~,-", \fll_, ¡: V), t. - In. feet feet Length Size MD TVD Burst Collapse 364' 26" 364' 364' 560' 17-3/4" 560' 560' 3,978' 13-3/8" 3,978' 2,790' 3,090 psi 1 ,540 psi 10,162' 9-5/8" 10,162' 8,294' 6,870 psi 4,760 psi 5,436' 7" 12,140' 10,153' 8,160 psi 7,020 psi Measured depth: 11,197' to 11, 569' True Vertical depth: 9,350 to 9,697' Tubing: (size, grade, and measured depth) 4-1/2", 12.6Ib./ft., N-80 Butt. from 36' to 327'; 3-1/2", 9.3Ib./ft., N-80 Butt. from 327' to 10,841' Packers and SSSV (type and measured depth) Baker Model'F' permanent packer at 10,760'; 3-1/2" Halliburton 'LXA' TRSSSV at 327' 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS BFl AUG 3 1 2U.o5 Treatment descriptions including volumes used and final pressure: n/a Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 128 817 1100 122 675 1100 15. Well Class after proposed work: Exploratory 0 Development 0 16. Well Status after proposed work: Oil 0 Gas 0 WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations 13. Oil-Bbl 104 120 Tubing Pressure 120 120 Service 0 x GINJ 0 WINJ 0 WDSPL 0 Sundry Number or N/A if C.O. Exempt: n/a Contact Steve Tyler 263-7649 Printed Name Timothy C. Brandenburg -:z---~~, / y..,. Signature ( __V <-/ J __ ,~<:: L.-/ '~ Form 10-404 Revised 04/2004 Title Drilling Manager "",,9 "::> .-.. c::-- Date ð -- ¿..b ._~ Phone 907-276-7600 OA~114Gi! N A L Submit Original Only t ~ UNOCALe L L ¿ Toe @ 10030' ,- :c E M E N T¿ 2 -II] 3 4 5 6 7 ~ 8 9 10 11 ~ 12 13 14 15 ~ 'X 16 17 "--/ 18 ~ 20 ~. 1Q G-5 Perfs HB-l HB-2 HB-3 11,826' ETD (Fill) 3/12/98 PBTD = 11,850' ETD = 12,140' Max angle = 58° @ 2526' ii' ~ Trading Bay Unit, Grayling Platform Well G-17RD Actual Completion, 8/2/05 ~ SIZE WT 26" 17 -3/4" Spiral 13-3/8" 61 9-5/8" 47 7"Liner 29 Tubing: 3 -1 /2" 9 . 3 4-1/2" 12.6 1 0,841 ' SSSV 327' GRADE TOP Surf Weld Surf J-55 Surf N-80/S-95 Surf N-80 9655' BTM LENGTH 364' 560' 3978" (Top of Window) 10,162' 12,140' 2485' N-80 Butt SSSV N-80 Butt Surf. JEWELRY DETAIL NO. Depth Item 1. 36' 4-1/2" EUE TBG Hangar 2. 327' 4-1/2" 12.6 lb/ft Butt Tbg 3. 327' 3-1/2" HES "LXA" TRSSSV (2.8l3"ID) 4. 2612' 3-1/2"9.2lb/ftButtTbg. 5.-15. Macco 3-1/2" GLM's at 2612',5245',6606', 7391',7856', 8321',8815',9280',9744',10210',10706' 16. 10,756' Locator Seal Assy w/15' seal bore extension 17. 10,760' Baker Model F Permanent Packer (4" ID) 18. 10,764' Seal Bore Extension 15' w/crossover 19. 10,808' Baker "X" nipple profile 20. 10,841' WLREG Perforation Record TOP BTM ZONE SPF DATE COMMENTS 4006 4007 NA 4HPF Feb-78 Squeezed 4114 4115 NA 4HPF Feb-78 Squeezed 11197 11216 G-5 6HPF Apr -98 Open 11252 11278 G-5 6HPF Apr-98 Open 11375 11412 HB-1 6HPF Mar-98 Open 11382 11412 HB-1 4HPF Mar-78 Open 11382 11412 HB-1 4HPF Sep-78 Open 11382 11412 HB-1 Mar-89 Open 11382 11412 HB-1 6HPF Mar-91 Open 11430 11450 HB-2 6HPF Mar-98 Open 11432 11512 HB-2 4HPF Mar-78 Open 11432 11512 HB-2 4HPF Sep-78 Open 11432 11512 HB-2 Mar-89 Open 11432 11512 HB-2 6HPF Mar-91 Open 11450 11512 HB-2 6HPF Mar-98 Open 11522 11 550 HB-3 6HPF Mar-98 Open 11535 11570 HB-3 4HPF Mar-78 Open 11535 11570 HB-3 4HPF Sep-78 Open 11 535 11570 HB-3 Mar-89 11535 11570 HB-3 6HPF Mar-91 Open 11535 11 569 HB-3 6HPF Oct -94 Open G 17RDSchem 08-05 REVISED: 8/26/2005 BY: DED Well Name G-17RD Primary Job Type _Perforating Jobs Lease/Serial ADL0017594 ¡Primary Wellbore Affected Main Hole AFE No, QC Eng 164193 Daily Operations 7/30/2005 00:00 - 7/31/2005 00:00 Operations Summary PJSM RU Eline. RIH w/2.5" x 18', 6 spf, 60 phase, HC perf gun Tbg Pressure = 1000 psi w/well SI. Tight spot at 8,600'. Tools sticking in tight area. RD Eline. RU slickline. RIH with jars, spangs and GR. Cleaned up tight spot. POOH. 7/31/200500:00 - 8/1/2005 00:00 Operations Summary RIH w/ 2.5" x 30' dummy gun. to 11,700', RD slickline. Safety meeting. RU Eline. RIH w 2.5" x 10' HC, 6 spf, 60 degree phasing perf gun, with wt and CCL. Tied in w/ Schlum. PDC GR/CCL log for all shots, TP - 1000 psi Spotted gun and fired 11,618' - 11,628'. POOH, RIH w 20' gun. TP - 1050 psi Spotted gun and fired 11,543 - 11,563'. POOH. RIH w 20' gun. TP - 1,050 psi Spotted gun and fired 11,529' - 11,543'. POOH. RIH w 30' gun. TP- 1050 psi. Spotted gun and fired 11,479' - 11,509'. POOH. RIH w 30' gun. TP -1050 psi. Spotted gun and fired 11,449' -11,479'. POOH. Secured well. 8/1/200500:00 - 8/2/2005 00:00 Operations Summary RU. RIH w 20' HC, 6 spf, 60 degrees phasing, gun. Tied in all runs with Schlum. PDC GRlCCL log. TP=1050 psi Spotted gun and fired 11,433 - 11,449'. POOH. RIH w 30' gun. TP = 1050 psi Spotted gun and fired 11,387' - 11,416'. POOH. RIH w 30' gun. TP=1050 psi. Spotted gun and fired 11,249 - 11,279'. POOH. RIH w 30' gun. TP=1050psi Spotted gun and fired 11,219' - 11,249'. POOH. RIH w 20' gun. TP - 1080 psi. Tools set down at 10,996'. POOH and RD. Turned well over to production. . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission f--....~·, ~)- . -~ DATE: July 10.2006 TO: Jim Regg P. I. Supervisor FROM: Chuck Scheve, Petroleum Inspector Grayling Platform SUBJECT: No Flow Trading Bay Unit G-17RD PTD# 1780030 Monday, July 10. 2006: I traveled to Unocal's Grayling Platform and witnessed a no-flow test on well G-17RD. I arrived on location and found the well bled off and opened to atmosphere with no flow of gas or fluid evident. The well was shut in and observed for three hours with a 15psi pressure build up observed. When reopened a peak flow of 300 seth was observed this flow decreased to 0 in 5 minutes. I recommend Well G-17RD on the Grayling Platform be approved no flow status for the purpose of removing the Sub Surface Safety Valve. SUMMARY: Well G-17RD meets the AOGCC requirements for no flow status. iiCANNED SEP 0 ß 200B .--..".. .......«-. (~i'l >~ l~) J [7\ I"' r:\ ^ \ [^ lü~\.II. I ß \.\ r-' I I ('"" \ L ' L,! ¡ . ~-~ L FRANK H. MURKOWSKI, GOVERNOR AI¡ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 June 23, 2004 Dwight Johnson Field Superintendent Unoca1 PO Box 196247 Anchorage, Alaska 99519 RE: No-Flow Verification Trading Bay Unit G-01RD, PTD 191-139 G-02RD, PTD 182-067 G-17RD, PTD 178-003 G-28RD, PTD 200-038 Dear Mr. Johnson: On May 27, 2004, AOGCC Petroleum Inspector John Spaulding witnessed "no flow tests" at Unoca1's Grayling platform, Trading Bay Unit, Wells G-01RD (short and long string completions), G-02RD, G-17RD, and G-28RD. Each well was opened to atmosphere through flow measurement equipment with suitable range and accuracy and monitored. An immeasurable flow of gas and no liquid hydrocarbons were produced to surface during the test. The subsurface safety valve may be removed from service in each of the wells listed above based on the no-flow test results. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in each well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service in any well that demonstrates an ability to flow unassisted to surface. Please retain a copy of this letter on the Grayling platform. Sincerely, /, ~í) (j~ D, )~~c James B. Regg 17 Petroleum Inspection Supervisor cc: Bob Fleckenstein pTD -----. i 01.-- Db 7 :{ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg . KCdtj k{pjetr" P. I. Supervisor (( DATE: June 22,2004 FROM: John Spaulding, Petroleum Inspector SUBJECT: uNo Flows" Unocal Grayling Platform 5 wells \f\ ~ ---bc0 June 15, 2004: I traveled to Unocal's Grayling platform to witness uNo Flows" on 5 wells, defined as follows. The platform was shut in for some upgrades while I was there. All wells were ready to commence testing upon my arrival. The same bleeding and testing procedures were used on all 5 wells. G-2RD: Well was bled to the well clean tank and after sufficient bled was then vented to atmosphere. Gas flow was positive but not measurable, no fluids observed. Recommend for no flow status. }1't>--cD3 G-17RD: Positive but not measurable gas flow, no fluids observed. Recommend for no flow status. '2eo-D'3~ G-28RD: Positive but not measurable gas flow, no fluids observed. Recommend for no flow status. I~l- 139 G-1 RDL: Positive but not measurable gas flow, no fluids observed. Recommend for no flow status. G-1 RDS: Positive but not measurable gas flow, no fluids observed. Recommend for no flow status. SUMMARY; I witnessed the successful no flow tests on the Grayling Platform Attachments: none NON-CONFIDENTIAL 2004-0615_no_flows- TBU_Grayling(5wells).doc Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOr. J Le Dan Williamson Drilling Manager Wednesday, March 22, 2000 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Mr. Robert Christensen Subject: Trading Bay Unit Well G-17rd APl No. 50-733-20161-01 10-404 Perforate G-Zone Dear Mr. Christensen: Please find enclosed in duplicate Form 10-404 for the perforation of the G5 bench in well G-17rd. This work was done on April 12, 1998 following a workover of the well. However, the perforating was not reported in the 10-404 that was submitted subsequent to the workover. I apologize for the oversight which was brought to our attention by Mr. Steve McMains. The following intervals were perforated: Bench Top Bottom Feet G5 11,197 11,216 19 G5 11,252 11,278 26 Total: 45 If you have any-questions, please contact Ralph Holman at 263-7838. )/~erely, ,-, ~.~, Dan Williamson Drilling Manager STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: Alter casing: Repair well: Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil of California (Unocal) Development: X 103' RT to MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: Trading Bay Unit P.O. Box 196247 Anchorage, Alaska 99519-6247 Service: 4. Location of well at surface 8. Well number 1832' FSL, 1488' FEL, Sec. 29, T9N, R13W, SM G-17rd At top of productive interval 9. Permit number/approval number 1459' FSL, 1277' FEL, Sec. 30, T9N, R13W, SM 68-108 At effective depth 10. APl number 1929' FNL, 1684' FEL, Sec. 30, T9N, R13W, SM 50-733-20161-01 At total depth 11. Field/Pool 1957' FSL, 1745' FEL, Sec. 30, T9N, R13W, SM McArthur River Hemlock/G 12. Present well condition summary Total depth: measured 12,140 feet Plugs (measured) true vertical 10,153 feet Effective depth: measured 11,950 feet Junk (measured) true vertical 9975 feet Casing Length Size Cemented Measured depth True vertical depth Structural 364' 26" Driven 364' 364' Conductor 560' 17-3/4" 625 sx 560' 560' Surface 3978' 13-3/8" 2500 sx 3978' 2790' Intermediate Production 12,009' 9-5/8" 3075 sx 10,162' 8294' Liner 5436' 7" 420 sx 9655'- 12,140' 7810'- 10,153' Perforation depth: measured 11197-11216, 11252-11278, 11375-11412, 11430-11512, 11522-11570 true vertical 9353-9371,9404-9428, 9519-9553, 9570-9647, 9656-9701 Tubing (size, grade, and measured depth) 4-1/2", 12.6 lb./ff., N-80 Butt. from 36' to 327'; 3-1/2", 9.3 lb./ff., N-80 Butt. from 327' to 10,841' Packers and SSSV (type and measured depth) Baker Model 'F' permanent packer at 10,760'; 3-1/2" Halliburton 'LXA' TRSSSV at 327' · 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure · ~ :, ~ :~:.: . 14, Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 214 104 348 1040 140 Subsequent to operation 287 73 652 1020 105 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: Oil: X Gas: Suspended: Service: 17, I hereby certify that the foregoing is true and correct to the best of my knowledge: Form 10-404 Rev 06/15/88 V SUBMIT IN DUPLICATE APr,Id, I~U 1~O,3~Ud F, Well: Facility: Field: Le~: Conductor: API #: AFE #: Z'UUFM UNUUAL UUKF, G.17rd Grayling Platform McArthur River 4 23 50-733-20161-01 130163 UNOCAL TOP BOTTgM Z~,,,I~E, , SPF 4,006 4,007 NA 4 4,114 4,115 NA 4 11,382 11,412 HB1 4 11,432 11,512 HB2 4 11,535 11,570 HB3 4 11,382 11,412 HB1 4 11,432 11,512 HB2 4 '11,535 11,570 HB3 4 11,382 11,412 HB1 11,432 11,512 HB2 11,535 11,570 HB3 11,382 11,412 HBI 6 11,432 I1,512 HB2 6 11,535 11,570 HB3 6 11,535 11,569 HB3 6 11,522 11,550 HB3 6 11,375 11,412 HB1 6 11,430 11,512 HB2 6 11,197 11,216 G5 11,252 11,278 G5 DATE ................ ,COMMENTS 2/78 Sqzd 2/78 Sqzd 3/78 Open 3/78 Open 3/78 Open 9/78 Open 9/78 Open 9/78 Open 3/89 Open 3/89 Open 3/89 Open 3/91 Open 3/91 Open 3/91 Open 10/94 Open 3/98 Open 3/98 Open 3~98 Open Proposed Proposed Post-IP Fax Note 7671 Co,IDem, Phone # Fax ~' Phone # Fax # O-17rd l~f info for Blair 4-13-98 Ralph P. Holmnn 04113198 RECEIVED Page 1 Unocal Corporation P.O. Box 196247 Anchorage, AK 99519 (907) 276-7600 UNOCAL ) Dale Haines Drilling Manager Monday, April 6, 1998 Mr. Blair Wondzell AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Application For Sundry Approvals (10-403) Grayling Platform No. 17rd Dear Mr. Wondzell: Please find enclosed an Application For Sundry Approval (Form 10-403) for the Grayling Platform No. 17rd in the McArthur River Field. This application requests approval for the perforation of the G5 zone in the following intervals: 11,252' - 11,278' 26' 11,197'- 11,216' 19' Total 45' This zone has not been previously perforated in this well. If you should have any questions regarding this application please contact Hal Martin at 263-7675. Thank you for your attention to these matters. Sincerely, Dale Haines Drilling Manager Enclosu res ...... STATE OF ALASKA ALASKA OIL GAS CONSERVATION C(JMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: X Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil of California (Unocal) Development: x 103' RT to MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 Service: Trading Bay Unit 4. Location of well at surface 8. Well number 1832' FSL, 1488' FEL, Sec. 29, T9N, R13W, S.M. G-17RD At top of productive interval 9. Permit number 1818' FSL, 1520' FEL, Sec. 30, T9N, R13W, S.M. ~ ~'~ At effective depth 10. APl number 1929' FNL, 1684' FEL, Sec. 30, T9N, R13W, S.M. 50-733-20161-01 , At total depth 11. Field/Pool 1957' FSL, 1745' FEL, Sec. 30, T9N, R12W, S.M. McArthur River- He~loc:;k 12. Present well condition summary Total depth: measured 12,140' feet Plugs (measured) true ve~ical 10,153' feet Effective depth: measured 11,950' feet Junk (measured) true ve~ical 9975' feet t~F:S~':~: Casing Length Size Cemented Measured depth True ve~ical depth Structural 364 26" Driven 364' 364' Conductor 560' 17-3/4" 625 sx 560' 560' Surface 3978' 13-3/8" 2500 sx 3978' 2790' Intermediate Production 12,009' 9-5/8" 3075 sx 10162' 8294' Liner 5436' 7" 420 sx 9655'-12140' 7810'-10,153' Pedoration depth: measured See attached true ve,ica, 'ORIGINAL Tubing (size, grade, and measured depth) 4-1/2", ~ 2.6 ~/~., N-80 Butt from 36' to 327', 3-1/2" N-80 butt from 327' to ~ 0,841' Packers and 888V (type and measured depth) Baker Model F Permanent Packer at ~0,760', 3-~/2" HallibuAon "LXA" TRSSSV at 327' 13. Attachements Description summa~ of proposal: x Detailed operations program: BOP sketch: Directional Program Wellbore schematic, letter 14. Estimated date for commencing operation 15. Status of well classification 4-10-98 16. If proposal well verbally approved: ~ Oil: Gas: Suspended: Name of approver Date approved Se~ice: Water Injector 17. I hereby ce~ify that the foregoing is true and correct to the best of my knowledge. Signed: Dale Haines ~ ~~ Title: Drilling Manager Date: 4-6-98 FOR COMMISSION USE ONLY Conditions of approvah Noti~ Commission so representative may witness ~lu~ intoority BO~ lost ~ kocation clearance Mechanical Integrity lost Subsequont form roquimd ~0- ~0 ~ Oo~q Approved by order of the Commissioner 0avid W. Johnston Co~sioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE - STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: X Alter casing: Repair well: Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California Development: X 103' RT to MSL feet 3. Address Exploratory: 7. Unit or Property name P.O. Box 196247, Anchorage, Alaska 99519-6247 Stratigraphic: Trading Bay Unit Service: 4. Location of well at surface 8. Well number 1832' FSL, 1488' FEL, Sec 29, TgN, R13W, SM. G-17RD At top of productive interval 9. Permit number/approval number 1818' FSL, 1520' FEE, Sec 30, TgN, R13W, S.M. ~ At effective depth 10. APl number 1929' FNL, 1684' FEL, Sec 30, T9N, R13W, S.M. 50-733-20161-01 At total depth 11. Field/Pool 1957', FSL,1745' FEL, Sec 30, T9N, R13W, S.M. McArthur River River- Hemlock 12. Present well condition summary Total depth: measured 12,140 feet Plugs (measured) true vertical 10,153 feet Effective depth: measured 11,950 feet Junk (measured) true vertical 9975 feet Casing Length Size Cemented Measured depth True vertical depth Structural 364' 26" Driven 364' 364' Conductor 560' 17-3/4" 625 sx 560' 560' Surface 3,978' 13-3/8" 2500 sx 3,978' 2790' Intermediate Production 12,009' 9-5/8" 3075 sx 10,162' 8294' Liner 5,436' 7" 420 sx 9,655'-12,140' 7,810'- 10,153' Perforation depth: measured See Attachment true vertical Tubing (size, grade, and measured depth) 4-1/2" 12.6 Ib/ft N-80 Butt from 36' to 327', 3-1/2" N-80 Butt from 327' to 10,841' Packers and SSSV (type and measured depth) Baker Model F Permanent Packer at 10,760', 3-1/2" Halliburton "LXA" TRSSSV at 327' 13. Stimulation or cement squeeze summary ~ ~ ~,, Intervals treated (measured) 0RIG IN A L Treatment description including volumes used and final pressure ;aJ~ska 0il & Gas Cons~ Com~.~issi°r~ 14. Representative Daily Average Production or Injection Data ~-..nchorage OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation (1/6/98) 260 84 323 585 160 Subsequent to operation (3/19/98) 372 17 602 1040 100 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: X Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: ._~~ ~t~ Title: ~;; l/il~, /~ ~,~ ~, Date: Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Grayling G-17RD Workover Summary of Operations Well work was required on G-17RD to correct recent abnormal declines in both gross and nett production. Perforation plugging and a tubing leak were suspected which hindered gas lift operations. The purpose of the workover was to restore productivity from the Hemlock producing interval of the well by replacing the failed tubing string. Following the workover access would be regained to the Hemlock interval allowing re-perforating of the existing open Hemlock Benches. Future plans are to run a RST and Production logs such that a decision can be made to add additional perforations in the G-5 interval. The general sequence of operations was as follows: Pulled existing 4-1/2" and 3-1/2" tapered gas lift completion. · Milled and recover existing permanent packer. · Ran a new 3-1/2" completion and returned the well to production. TOC ~ 10030' 20 16 17 8 Proposed G Perfs HB-1 HB-2 HB-3 11,826' ETD (Fill) 3/12/98 SIZE WT Trading Bay Unit, Grayling iPlatform Well G-17RD Actual Completion, 3/98 GIL4DE TOP iBTM LENGTH 26" 17-3/4" Spiral 13-3/8" 61 9-5/8" 47 7"Liner 29 Tubing: 3-1/2" 9.3 4-1/2" 12.6 Weld J-55 N-80/S-95 N-80 Surf 364' Surf 560' Surf 3978" (Top of Window) Surf 10,162' 9655' 12,140' 2485' N-80 Butt SSSV 10,841' N-80 Butt Surf. SSSV 327' JEWELRY DET.AIL NO. Depth. Item . 2. 3. 4. 5.-15. 2612', 9280', 16. 17. 18. 19. 20. 'roe 36' 4-1/2" EUE TBG Hangar 327' 4-1/2" 12.6 lb/ft Butt Tbg 327' 3-1/2" HES "LXA" TRSSSV (2.813"ID) 2612' 3-1/2" 9.2 lb/ft Butt Tbg. Macco 3-1/2" GLM' s at 5245', 6606', 7391', 7856', 8321', 8815', 9744', 10210', 10706' 10,756' Locator Seal Assy w/15' seal bore extension 10,760' Baker Model F Permanent Packer (4" ID) 10,764' Seal Bore Extension 15' w/crossover 10,808' Baker "X" nipple profile 10,841' WLREG Perforation Record BTM ZONE SPF D.ATE COiMMENTS 4OO6 4114 11382 11432 11535 11382 11432 11535 11382 11432 11535 11382 11432 11535 11535 11522 11375 11450 11430 4007 NA 4HPF 2/78 Sqzd 4115 NA 4HPF 2/78 Sqzd 11412 HB-1 4HPF 3/78 Open 11512 HB-2 4HPF 3/78 Open 11570 HB-3 4HPF 3/78 Open 11412 HB-1 4HPF 9/78 Open 11512 HB-2 4HPF 9/78 Open 11570 HB-3 4HPF 9/78 Open 11412 HB-1 3/89 Open 11512 HB-2 3/89 Open 11570 HB-3 3/89 Open 11412 HB-1 6HPF 3/91 Open 11512 HB-2 6HPF 3/91 Open 11570 HB-3 6HPF 3/91 Open 11569 HB-3 6HPF 10/94 Open 11550 HB-3 6HPF 3/98 Open 11412 HB-1 6HPF 3/98 Open 11512 HB-2 6HPF 3/98 Open 11450 HB-2 6HPF 3/98 Open PBTD = 11,850' ETD = 12,140' Max angle = 58° ~ 2526' CompletionG- 17RD.rtf. doc REVISED: 3/27/98 DRAWN BY: DNM MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission David Joh~ ChairmaQ~ Blair Wondzell,_~J2~,~ P. I. Supervisor ~(~/ee /I_ FROM' Lou Grimaldi,~¢,,-~ SUBJECT: Petroleum InSpector DATE: February 2, 1998 FILE NO: AU9JBAFE.DOC BOP Test, Grayling Unocal, Well #G-17RD McArthur River Field PTD #78-0003 Sunday, February 1, 1998; I witnessed the initial BOP test on the Grayling platform rig working over Grayling well #G-17RD in the McArthur River Field. I arrived to find the rig about four hours away from being ready to test. I made a cursory tour of the rig and its surrounding area and found all to be in good shape. The test, once started went slow but well with all BOPE being tested correctly and three failures observed. The Stroke counter on the Choke Panel was not wired in and was inoperative, also the gauge for the Choke panel that reads casing pressure would read accurately up to approximately 3000 psi and then stop moving. The sending unit for this gauge was purged and pressured up which did nothing to help the problem. There were also some lights indicating which rams were closed on the BOP out. The rig crew did a good job testing the BOPE and I found Paul Barr's (toolpusher) procedure to insure a methodical test of the BOP equipment. This is the initial test on this rig since activation. The rig was in Fair shape and showed evidence of the ongoing upgrade. SUMMARY: The initial BOPE test I witnessed on the Grayling rig revealed the following; Test hours 5, Failures 3. Attachments: AU9JBAFE.XLS CC; Dan Williamson (UNOCAL Anchorage) Dale Haines (UNOCAL Anchorage) NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Workover: X Drlg Contractor: Pool Arctic Rig No. Grayling PTD # Operator: Unocal; Rep.: Well Name: G-17RD Rig Rep.: Casing Size: Set @ Location: Sec.~ Test: Initia X* Weekly Other~ DATE: 2/1/98 78-0003 Rig Ph.# 770-6638 Paul Barr Mike McCall 29 T. 9N R. 13W Meridian Seward Test MISC. INSPECTIONS: Location Gen.: P Housekeeping: P (Gen) PTD On Location P Standing Order Posted P Well Sign P Drl. Rig P Hazard Sec. P FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. Pressure P/F 250/5,000 250/5,000 I 250/5,000 P 1 250/5,000 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F 1 250/3,000 P 1 250/5,000 P 1 250/5,000 P 1 250/5,000 P 1 250/5,000 P 1 250/5,000 P 2 250/5,000 P N/A 250/5,000 N/A MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P CHOKE MANIFOLD: No. Valves 13 No. Flanges Manual Chokes Hydraulic Chokes 2 Test Pressure P/F 250/5,000 P 28 250/5,000 P 1 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure ~ System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: Four Bottles 2000 average 3,000 I 1,400 minutes 48 sec. 3 minutes 58 sec. P Remote: P Psig. Numberof Failures: 3 ,Test Time: 5.0 Hours. Number of valves tested '/8 Repair or Replacement of Failed Equipment will be made within 3 days. otify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Some Lights on Rig floor BOP panel out, replace bulbs. Choke panel gauge although accurate up to 3000 psi, would not go higher. Stroke counter on choke panel was not hooked up yet. Gas Detectors calibrated whiletest was underway. Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES NO 24 HOUR NOTICE GIVEN YES NO Waived By: Witnessed By: Louis R. Grimaldi FI-021 L (Rev. 12/94) Au9jbafe.xls Ralph P. Holman Engineer Technician Unocal P.O. Box 196247 Anchorage, Alaska 99519-45247 March 15, 1995 Mr. Russ Douglas Commissioner Alaska Oil & Gas Conservation Co~mnission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Mr. Douglas: On October 27, 1994 the following intervals were perforated in well G-17RD (API 50-733-20161--01) in the McArthur River Field: BENCH TOP (MD) BOTTOM (MD) FEET I-[133 11,535 11,569 34 TOTAL 34 Sincerely, R ECEIVE[D AP~ £ 0 199b Aiaska 0it & Gas Cons. Commission Anchora, ..---_ STATE OF ALASKA -- ALAS OIL AND GAS CONSERVATION (. vlMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate Pull tubing Alter casing Plugging __ Perforate X_ Repair well Pull tubing _ Other__ 2. Name of Operator Unocal 3. Address P.O. Box 196247 Anchorage, Alaska 99519-6247 5. Type of Well: Development X_ Exploratory ~ Stmtigraphic __ 4. Location of well at surface Grayling Platform, Leg #4, Conductor #23 1832' FSL, 1488' FEL, Sec. 29, T9N, R13W, SM At top of productive interval 1818 FSL, 1520' FEL, Sec. 30, T9N, R13W, SM At effective depth 1929' FNL, 1684' FEL, Sec. 30, T9N, R13W, SM At total depth 1957' FSL, 1745' FEL, Sec. 30, T9N, R13W, SM 6. Datum eleva~n (DF or KB) 103' RT to MSL 7. Unit or Property name Trading Bay Unit 8. Well number G-17RD feet 9. Permit number/approval number 10. APl number 50-733-20161-01 11. Field/Pool McArthur River/Hemlock 12. Present well condition summary Total depth: measured true vertical 12,140 feet 10,153 feet Plugs (measured) Effective depth: measured 11,950 feet Junk (measured) true vertical 9,975 feet Casing Length Size Cemented Measured depth Structural 364' 26" D riven 364' Conductor 560' 17-3/4" 675 sx 560' Surface 3978' 13-3/8" 2500 sx 3978' Intermediate Production 10162' 9-5/8" 3075 sx 10162' Liner 2485' 7" 420 sx 9655' - 12140' Perforation depth: measured 11382' - 11412, 11432' - 1151Z, 11535' - 11570' True vertical depth '364' 560' 2790' 8294' 7810' - 10153' true vertical 9441' - 9469', 9488' - 9563', 9585' - 9617' Tubing (size, grade, and measured depth) 4-1/2", 12.6# & 3-1/2', 9.2# N-80 buttress Packers and SSSV (type and measured depth) Baker FB-1 pkr. @ 11,250', 4-1/2" Otis BY (~ 322' D-I: C r. I T I E ~ ~.. ~.., i, I V I,~ ~,~ 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure R 2 0 1995 Gas Cons. Commiss ~choraf-~ 14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run__ Daily Report of Well Operations Representative DailyAverage Production orlnjecflon Daa OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 449 132 365 610 462 'j 92 424 650 Tubing Pressure 140 145 16. Status of well classification as: Oil X_ Gas __ Suspended Service 17. I here~v certi.fy that t~e for,egoi~ng is true and correct to the best of my knowledge. Signed ~ ~-.~J~~' Title Form 10~ Rev 06/15/~ Date ~[ t~ {c[~ SUBMIT IN DUPLICATE ALASIO-'ML AND GAS CONSERVATION CO.~'=41SSION APPLICA 'ION FOR SUNDRY AP. ROYALS 1. Type of request: Abandon __ Suspend __ Alter oaaing__ Repair well Change approved program __ Operations shutdown __ Re-enter suspended well__ Plugging __ Time extenaion __ Stimulate __ Pull tubing ~ Varlanoe __ Perforate X_ Other__ 2. Name of Operator Unocal 3. Address P.O. Box 196247 Anchorage, Alaska 99519-6247 5. Type of Well: 4. Location of well at surface Grayling Platform, Leg 4, Conductor 23, 1832' FSL, 1488' FEL, Sec. 29, T9N, R13W, SM At top of productive interval 1818' FSL, 1520' FEL, Sec. 30, T9N, R13W, SM At effective depth 1929' FNL, 1684' FEL, Sec. 30, T9N, R13W, SM At total depth 1957' FSL, 1745' FEL, Sec. 30, T9N, R13W, SM 6. Datum elevation (DF or KB) KB: 103' above MSt. 7. Unit or Property name Trading Bay Unit 8. Well number G-17RD 9. Permit number 78 -00O3 -0 10. APl number 50-733-20161-01 11. Field/Pool McArthur River/Hemlock feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 12140 feet Plugs (measured) 10153 feet 11950 feet Junk (measured) 9975 feet Casing Structural Conductor Surface Intermediate Production Uner Length Size Cemented Measured depth 364' 26" Driven 364' 560' 17-3/4' 675 sx 560' 3978' 13-3/8' 2500 sx 3978' 10162' 2485' Perforation depth: measured 9-5/8' 3075 sx 10162' 7' 420 sx 9655'- 12140' 11382-11412, 11432-11512, 11535-11570 true vertical 9441-9469, 9488-9563, 9585-9617 Tubing (size, grade, and measured depth) 4-1/2', 12.6# & 3-1/2', 9.2# N-80 buttress Packers and SSSV (type and measured depth) True vertical depth 364' 560' 2790' 8294' 7810'-10153' R£C£1VED S EP 25 1994 Baker FB1 pkr. @ 11250', 4-1/2' Otis BV @ 322'AlaSka 0il & Gas Cons. Comrni~ Anchor~e. 13. Attachments Description summary of proposal __ Detailed operations prograrnX~ BOP sketch Questions? Call Hal Martin @ 263-7675 or Ralph Holman (~)263-7838 14. Estimated date for commencing operation ri 5. status of well classification as: October 12, 1994 / 16. If proposal was verbally approved / Oil X_ Gas m Suspended m / Name of approver Date approvedI Se~lce 17. I her~tl~ cerl;Ey that ~e~ forpgg, in~d correct to the best of my knowledge. Signedkj~ [//.y:~. ~.~/L~C.~N,.-,,~.~-v.~()() y~(~ ~.C._~ Title~I, LL, L/~C..k ~"~/~,~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug Integrity _ BOP Test Location clearance Mechanical Integrity Test__ Subsequent form required 10- IApproval No. Approved by the order of the Commission Form 10-403 Rev 06/15/88 JrLginal Signed By ~vid W, Johnston Commissioner Approved Copy Returned SUBMIT IN TRI'PLIOME ion Ralph P. Holman Engineer Technician Unocal P.O. Box 196247 Anchorage, Alaska 99519-6247 September 20, 1994 Mr. Russ Douglas Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Mr. Douglas: This is to inform you of Unocal's intent, upon your approval, to perforate the following intervals in well G-17RD (API# 50-733-20161-01) on the Grayling platform. BENCH TOP (MD) BOTI'OM (MD) FEET HB1 11382 ¢' 11412 30 I-IB2 11432 11512 80 HB3 11535 11569 '/ 34 TOTAL 144' Sincerely,/.../ / /~ REEEIV£D SEP 2 3 1994 Alaska Oil & Gas CoDs. Commission Anchorr~ September 20, 1994 Grayling Platform, Well G-17RD Perforating Procedure 1. Hold safety meeting. 2. Rig up electric line unit. . Pressure test lubricator as directed by Unocal wire.ss for five minutes. Note: A pumpdn sub with a valve is required. 4. Shut down all welding and radio transmissions. . Run in hole and perforate intervals as instructed by Unocal wire,ss. (When gun is 200' below surface, welding and radio transmissions may resume.) Pull out of hole. (When gun is 200' below surface, shut down all welding and radio transmissions.) 7. Repeat steps 5,6 and 7 as needed to perforate the following intervals: BENCH INTERVAL FEET HB1 11382-11412 30 HB2 11432-11512 80 I-IB3 11535-11569 34 TOTAL: 144 RECEIVED SEP 2 3 1994 Aiaska Oil & Gas Cons. Commission Anchor~;e Unocal North American Oil & Gas Division Unocal Corporation P.O, Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region October 7, 1993 Ms. Joan Miller Statistical Technician Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Ms. Miller: On November 4, 1991 the following intervals were perforated in well G-17RD at 6 shots per foot, 0° phasing: BENCH TOP BOTTOM TOTAL HB1 11,382' 11,412' 30' HB2 11,432' 11,512' 80' HB3 11,535' 11,570' 35___[' TOTAL 145' Ralph P. Hohnan Engineer Technician RPH/rph Anehora~o ..... STATE OF ALASKA ALASKA _AND GAS CONSERVATION COt~ :SSION REPORT OF SUNDRY WELL OPF_., ATIONS Operations performed: Operation shutdown __ Stimulate __ Plugging __ Perforate X_ Pull tubing __ Alter casing__ Repair well __ Pull tubing __ Other . . Name of Operator Unocal Address P.O. Box 196247 Anchorage, Alaska 99519-6247 5. Type of Well: Development X Exploratory __ Stratigraphic __ -- Location of well at ~surface Grayling Platform, Leg #4, Conductor #23 1832' ESL, 1488' ,~; i!~i... Sec. 29, T9N, R13W, SM At top of productiv~,nterval 1818 FSL, 1520' FEL, Sec. 30, T9N, R13W, SM At effective depth 1929' FNL, 1684' FEL, Sec. 30, T9N, R13W, SM At total depth 1957' FSL, 1745' FEL, Sec. 30, T9N, R13W, SM 6. Datum elevation (DF or KB) 103' RT to MSL 7. Unit or Property name Trading Bay Unit 8. Well number G-17RD feet 9. Permit number/approval number 6.S.---tO8/91-331 10. APl number 50-733-20161-01 11. Field/Pool McArthur River/Hemlock 12. Present well condition summary Total depth: measured true vertical Effective depths: measured true vertical 12,140 feet Plugs (measured) 10,153 feet 11,950 feet Junk (measured) 9,975 feet Casing Length Structural 364' Conductor 560' Surface 3978' Intermediat~ Production 10162' Liner 2485' Perforation d~pth: measured Size Cemented Measured depth True vertical depth 26" Driven 364' '364' 17-3/4" 675 sx 560' 560' 13-3/8" 2500 sx 3978' 2790' 9-5/8" 3075 sx 10162' 7" 420 sx 9655' - 12140' 11382' - 11412, 11432' - 11512,, 11535' - 11570' 8294' 7810'- 10153' true vertical 9441' - 9469', 9488' - 9563', 9585' - 9617' Tubing (size, grade, and measured depth) 4-1/2% 12.6# & 3-1/2", 9.2# N-80 buttress Packers and SSSV (type and measured depth) Baker FB-1 pkr. @ 11,250', 4-1/2" Otis BV @ 322' 13. Stimulation ~r cement squeeze summary Intervals treated (measured) Treatment d~scription including volumes used and final pressure 0CT 19 1993 Alaska 0il & Gas Cons. Commis," Anch0~ag~ 14. Prior to well c~peration Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 396 103 374 830 Tubing Pressure 130 Subsequent l.o operation 15. Attachmeni~---- Copies of I.!iogs and Surveys run Daily Repq'~t of Well Operations ___~ 489 268 588 660 150 16. Status of well classification as: Oil X_ Gas _ Suspended Service 7. I hereby ceitify that the foregoing is true and correct to the best of my knowledge. Signed '~,~~~~'~[/~ ,, Title Form 10-404 Rev 06/15/88 Date / '.~/~/~'~ SUBMIT IN DUPLICATE ALASKA OIL AND GAS CONSERVATION COM~IISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 14, 1993 Mr. G. Russell Schmidt Drilling Manager UNOCAL P.O. Box 190247 Anchorage, Ak. 99519-0247 Re: Trading Bay Unit, AOGCC Forms 10-403 and 10-404 Dear Mr. Schmidt, In conducting an audit of well files I have found a number of wells containing approved Application of Sundry Approval forms (form 10-403) with no subsequent Report of Sundry Well Operations (form 10-404). Enclosed is a list of the wells in question. To be in compliance with AS'20 AAC 25.280(d) of the Regulations, the Form 10-404 is required to be filed within 30 days following completion of work. In previous telephone conversations concerning the subject, it had beeq_explained to me that either ARCO or Marathon had been th~l~operator on the majodty of the work proposed; however, it is the feeling of the Commission that if the work was completed, it is UNOCAL's responsibility to see that the appropriate papenvork be filed in a timely manner inasmuch as UNOCAL is the operator of the field and UNOCAL personnel signed the Application' of Sundry Approval forms. Your assistance in supplying us with the appropriate forms and in helping resolve this problem.in the future will be appreciated. We would also appreciate notification of any canceled Work so that the corresponding Application. on file can-be marked accordingly · Sincerely, · · Statistical Technician ~,.~) p~inled on recycled paper b y Well Perm/t No. No. D-4 82-41 D-5RD 80-65 D-26 74-9 D-27 75-24 D-40 82-83 D-42 83-53 D-46 89-61 Approval Date & No. 3-1-91, 91-060 5-31-91, 91-163 7-2-91, 91-188 11-22-91, 91-353 9-2-91, 91-189 9-20-91, 91-284 11-27-91, 91-361 5-21-91, 91-161 10-24-91, 91-317 5-31-91, 91-160 7-2-91~ 91-190 5-31-91, 91-162 12-11-91, 91-387 Trading Bay unit Description Perforate 2-91 Perforate 5-91 Workover 4~91 Perforate 11-91 Perforate 6-22-91 Reperf HB4/Pump Clay Stab. 9-10-91 Stimulate 12-8-91 CT Cleanout 5-28-91 Reperf. HB2,3&$4 10-3-91 Perf 5-91 Scale Cleanout 6-20-91 Perf 5-91 Reperf HB-2 11-91 10-403 Signed_ By G. Bush G. Bush G. Bush G. Bush G. Bush G. Bush G. Bush G. Bush G. Bush · G. Bush G-5 67-71 3/15-91, 91-086 _ _ .. G-6 82-33 10-30-91, 91-325 4-21-92, 92-093 Short & long inj. profile (If work was completed the 10-403 required a 10-407, Completion, Recompletion. report for this wel~.. Perf. 10-19-91 Perf 4-92 . G. Bush G. Bush G. Bush G-17 ~:78~3 11-1-91, 912331 G-19 69-17 11-10-92, 92-238 G-21 72-42 4-21-92, 92-094 -' - 6-17-93, 93-154 . G-27 78-70 4-21-92, 92-95 1-6-93, 92-203 · G-31 69-72 3-21-91, 91-95 K-1 67-65 2-9-90, 90-082 K-2RD 78-38 10-11-88, 8-771 6-8-90, 90-440 7-9-91, 91-197 K-3 80-144 2-9-90, 90-081 K-9 68-38 11-14-89, 9-987 Perforate G. Bush Temp. log 10-15-92 ., G. Bush Perf. 4-92 Coil tubing cleanout Perforate Convert to inj. Production profile G. Bush Perforate 2/90 R. Roberts Perf., cement squeeze Stim, p. tubing, perf. 6-90 Perforate 6-91 R. Roberts G. Bush G. Bush Perforate 2/90 R. Roberts Repair well, p. tubing, stimulate, perforate R. Roberts STATE OF ALASKA ALASKA el L AN D GAS CONSERVATION COM MISSION APPLICATION FOR SUNDRY APPROVAL RI Gl 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pull tubing __ Variance __ Perforate __x Other __ 2. Name of Op_erator Union Oil Company 3. Address P. O. Box 196247, of California (Unocal) Anchorage, AK 99519 5. Type of Well: Development x Exploratory __ Stratigraphic __ Service __ 4. Location of well at surface Condo #23, Leg #4 1832' FSL, 1488' FEL, Sec. 29, T9N, R13W, SM At top of productive interval 1818' FSL, 1520' FEL, Sec. 30, T9N, R13W, SM At effective depth 1929' FNL, 1684' FEL, Sec. 30, T9N, R13W, SM At total depth 1957' FSL, 1745' FEL, Sec. 30, T9N, R13W, SM 6. Datum elevation (DF or KB) 103' RT to MSL 7. Unit or Property name Trading Bay Unit 8. Well number G-17RD 9. Permit number 68-108 10. APl number 50--733-20161-01 11. Field/Pool feet McArthur River/Hemlock 12. Present well condition summary Totatdepth: measured 12,140 true vertical 10,153 feet Plugs (measured) feet Effective depth: measured 11,950 true vertical 9,975 feet Junk (measured) feet Casing Structural Conductor Sudace Intermediate Production Liner Perforation depth: ~ngth Size Cemented 364' 26" Driven 560' 17 3/4" 675 sx 3,978' 13 3/8" 2,500 sx RECEIVED 0 CT 3 1 Alaska Oil & Gas Cor~s. Commissio. Measured depthAilCJ'10ra~,eTrue vertical depth 364' 364' 560' 560' 3,978' 2,790' 10,162' 9 5/8" 3,075 SX 10,162' 8,294' 2,485' 7" 420 SX 9,655' - 12,140' 7,810'-10,153' measured 11,382'-11,412'; 11,432'-11,512'; 11,535'-11,570' truevertical 9,441'-9,469'; 9,488'-9,563'; 9,585'-9,617' Tubing (size. grade, and measured depttq) 4 1/2", 12.6# & 3 1/2", 9.2# N-80 Buttress Packers and SSSV (type and measured depth) Baker FB-1 Pkr. @ 11,250', 4 1/2" Otis BV @ 322' 13. Attachments Description summary of proposal __ Detailed operations program .,% BOP sketch __ 14. Estimated date for commencing operation 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~ Gas __ Suspended __ Service 17. I hereby cd, fy that the foregoing is true and correct to the best of my knowledge. Signed [ ~,.~~ ~, (~,¢.~ Title ~ .¢'~ FOR COMMISSION USE ONLY Conditions of al~val:~tify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY . ApprOved C.oP¥ Returned Commissioner Date /o - 2.'?.-~ \ lApp,ova, Date //-" j--¢/[~. SUBMIT IN TRIPLICATE October 21, 1991 G-17RD Perforatinq Procedure 1. RU slick line, run gauge and tag bottom. 2. Hold saftey meeting. 3. RU electric line unit. 4. Pressure test lubricator to 2,500 psi for five minutes. 5. Shut down all welding and radio transmissions. , o RIH and perforate intervals as instructed by Unocal representative (welding & radio transmissions may resume when gun is 200' below surface). POOH (shut down all welding and radio transmissions). . Repeat steps 5, 6 & 7 as needed to perforate in the following intervals: HB#1 HB#2 HB#3 Measured: 11,372'-11,412' 40' Measured: 11,432'-11,512' 80' Measured: 11,520'-11,600' 80' ~.200' GRAYLING DISTANCE & DIRECTIONS FROM SE CORNER SEC. 29, TgN, R13W CONDUCTOR LEG if3: EAT = 60050' 22.569" LONG =151°36' 46.519" "Y" COORD. "X" COORD. WELL # FSL 2,502,352.30 212,272.70 1804 1 2 3 4 5 6 7 8 9 lO 11 12 2,502,346.65 212,269.32 G-22 1789 2,502,350.14 212,266.48 G-21 1802 2,502,354.64 212,266.55 G-26 1806 2,502,358.05 212,269.49 G-25 1810 2,502,358.77 212,273.94' G-24 1810 2,502,356.46 212,277.80 G-20 1808 2,502,352.20 212,279.28 1804 2,502,347.99 21 2,277.68 G- 36 1800 · . 2,502,345.80 212,273.75 G-34 & RD 1798 2,502,350.83 212,270.89 G-23 & RD 1803 2,502,354.60 212,272.33 G-33 1806 2,502,351.47 212,274.88 G-27 & 28 1803 LEG ~4: LAT = 60050' 22.832" LONG =151°36' 48. 042" 2,502,380.80 212,197.90 1831 13 14 15 16 17 18 19 20 21 22 23 24 2,502,374.34 212,196.66 G-14A 1825 2,502,376.65 212,192.79 G-19 1827 2,502,380.90 212,191.32 G-1 3 1831 2,502,385.11 212,192.92 G-15 1835 2,502,387.30 21 2,196.85 G-5 1838 2,502,386.45 212,201.28 1837 2,502,382.96 212,204.12 G-3 1833 2,502,378.46 212,204.05 G-2 1829 2,502,375.05 212,201.11 G-11 1825 2,502,378.50 212,198.27 G-lO 1829 2,502,381.63 212,195.72 G-17 & RD 1832 2,502,382.27 212,199.71 G-7 1832 LEG #1: 2,502,455.60 LAT = 60050' 23.575" LONG =151°36' 4Z. 505" ' 212,226.40 1906 (Reserved for Compressors) LEG #2' LAT = 60050' 23.313" LONG =151°36' 45. 982" 2,502,427.10 212,301.20 1880 37 38 39 40 41 42 43 44 45 46 47 48 2,502,421.45 212,297.82 G-1 2, 2,502,424.94 . 212,294.98 G-31 2. 502,429.4 5 212,295.05 G-4 2,502,432.85 212,297.99 G-1 2,502,433.57 212,302.44 G-9 2,502,431.26 212,306.31 G-18 2. 502,427. O0 212,307.78 G-14 RD&2 2,502,422.80 212,306.18 G-30 ........... 1 2'~502,420.60 ............. 212,302.25 ................. GL8 & RD 1 2,502,425.63 212,299.39 G-6 1 2,502,429.40 212,300.83 G-32 1 2,502,426.27 212,303.38 G-16 1 1874 1878 1882 1886 1886 1884 1880 876 874 879 882 879 FEL 1409 1413 1415 1415 1412 1408 · 1404 1402 1'404 1408 1411 1409 1407 1486 1487 1491 1493 1491 1487 1483 1480 1480 1486 1483 1488 1484 1458 1383 1386 1389 1389 1386 1382 ~/o 1376 .... 1378 ...... 1382 1385 1383 1381 Unocal Nor"tt't Ame Oil & Gas I~ivl:s~an PO. ~ox ~902~7 Anchorage. Alaska ~g519-0247 Atasxa Region April 16, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. A/~chorage, AK 99504 Attn: Ms. Elaine Johnson Dear Ms. JohnSon:· I have attached surface survey locations of the "Legs" and conductors for the four platforms in the Trading Bay Unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor but I hope this will meet your needs. Yaurs very truly, G sh ' Regional Drilling Manager GSB/lew STATE OF ALASKA 0 R ! ~ i ~ AL .... KA OIL AND GAS CONSERVATION COMMI. ON REPORT OF SUNDRY WELL OPERATIONS I. Operations performed: Operation shutdown __ Stimulate__ Plugging __ Perforate ,~ Pull tubing __ Alter casing __ Repair well __ Pull tubing __ Other __ 2. Name of .Operator Union Oil Company of California (UNOCAL) 3. Address P.O. Box 190247, Anch, Ak., 99519-0247 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface see ' TgN' R1 W sLea.4~9C°nduct°r3#,23~.1832' N and 1488' W from SE corner 6. D.a]um elevation (DF or KB) 99 RT to MSL 7. _U nit qr. Prope_rty na.m. e. _ 'z'ract',ng t~ay un:l'u 8. Well number G-17RD At top of productive interval 4402' N & 8263' W of At effective depth At total depth 4951' N & 8401' W of Surface Location Surface Location 9. Permit number/approval number 9-086 10. APl number 50-- 733-20161-01 11. Field/Pool McArthur River Field 12. Present well condition summary Total depth: measured true vertical Effective depth: 15,095' 10,230' measured 15,025' truevedical 10,181' ~ngth Size 364' 26" 560' 17-3/4" 6,456' 13-3/8" Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: feet feet Plugs (measured) feet feet Junk (measured) Cemented Measureddepth ~ueve~icaldepth 364' 364' 675sxs 560' 560' 2,825sxs 6,456' 4,443' 12,009' 9-5/8" 1,000sx 12,009' 10,227' 3,197' 7" 600sx 15,091 measured true vertical See Attached Tubing (size. grade, and measured depth) 4-1/2", 12.6#, N-80 & 3-1/2", 9.2#, N-80 @ 11,339'. Packers and SSSV (type and measured depBth~ker FB-1 11,250 ' SSSV: Otis 13. Stimulation or cement squeeze summary @ 322' 14. Intervals treated (measured) Treatment description including volumes used and final pressure Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 301 89 100 Subsequent to operation 601 624 110 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil .F_.. Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Roy~D'. Roberts ~._. Title Environmental Engineer Form 10-404 Rev 06/15/88 Date 5/12/89 feet SUBMIT IN DUPLICATE REPORT OF WELL OPERATIONS GRAYLING PLATFORM - WELL G-17RD On March 27, 1989, Well G-17RD was perforated using the following procedure: Rig up Halliburton Wireline Pressure test lubricator Run in hole with Halliburton Dyna-strip guns and perforate the following intervals at four shots per foot and zero degrees phasing: 11,373' - 11,412' MD 11,432' - 11,512' MD 11,520' - 11,595' MD POOH Rig down Well tests before and after were: Gross Net Cut Before: 390 301 23% After 1,225 601 51% TBUS G-17RD McARTHUR RIVER FIELD 'W 11 · CASING DE TA KELLY BUS~ING AT 'w,.,. -,- S~N'S_E "112" TUBING ~ :~6" C.¢-.,SING ,.r..,T ~ 1T 3/~",S~IR,r.C,WELS &T 560' Cm*,'¢ W/Z50O SXS,RETAINER AT,, 4050' ' ~ TO¢ 7",2P.'~, N-BD,BL]TT. ~ ~ 5~",47~,N-BOB 5- ?... E4JTT. , &T 10,162' (Cm~'¢ W/ZO?5 S345) ~ BOTTOm, 7' LINER, BaKER FLD ¢£7'///_ 4 1/2", ~2..6'~' B 3 1/2",9.2% N- BO, BUTTRESS TBG. I ~ 1/2" OTIS BSLL VALVE &T 2-E < 1/2" C.~M;O MMG" GAS LI.rT MANDR.'CLS AT: 2)25<~.71' ~) 525~.80'~4)6761.26'~ 5) 7746.~7 ';6) 8489.96'~ 7 ) 8972.3,4' CROSS-OVER ~t/2" X 4 1/2" ~ 1/2" CAMCO "MMG" GAS LI~T MANDRELS At: 101964~.4i~11) 16. 51/2" OTIS "X&" SLEEVE ~T I% B~KER LOS~T~ SUB 4j/4"X$" I.D[L~NED 2.16'0~ 16 BAKER SEAL ~eSY. 4"X ~" I.D.(~WER SE~ MULE SH~ZD) FROM 11.2~5.~' TO 11,26~.D4 19 BAKER 7"X4" MODEL FS-I P~RM. PA;K~R SET D.R II,25g' ~. 51/2"X 55/4" ORO% OVER AT ll,2T4.TS' Zi. ~I/2"X 2.~5"l.D. OTIS X NI~PLE AT 22. ~I/2"MULE SH~ AT PE ,FOt A T/ON HECOHD _ D&TE INTERVAL "- - '- P~F_Sr..N, CONDITION 2.[7178 41i~:'-- ~,.I15' IS,,OL&Ti.~N S;QU~EZE 2/7/78 ,r-.OD6.,'- 400T' (W/SOO SXS) ~/"28778 1',,582'-11,412~' PL=fD~':>;J:TIgN B-~N:H I ' ~' 11,570' PRDO;J2TIDN BEN:,H $I261'78 I.B.U.S. G-t7 RD · WELL · .... STATE OF ALASKA AL, ,oKa OIL AND GAS CONSERVATION COMM k.,,.,ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation shutdown __ Re-enter suspended well ~ Alter casing __ Repair well __ Plugging ~ Time extension ~ Stimulate __ Change approved program __ Pull tubing __ Variance __ Perforate ~ Other ~ 2. Name of Operator ! 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNI~CAL) Development~c_ ~9~ RT to MSL / Exploratory __ 3. Address ! Stratigraphic __ 7. U nit or Property name P.O. Box 190247, Anch, Ak., 99519-0~47 Service__ Tradlng Ba)LTn±t feet 4. Location of well at.surface Leg -~, uonauctor #23, 1832'N and 1488' Sc. 2 O¢l~roduc~i¢e TgN- R13W SM. At top interval ' 4402'N & 8263'W of surface location. At effective depth At total depth 4951'N & 8401'W of surface location. W from SE corner 9. Permit number 68-108 10. APl number 50-- 733-20] ~;1-0] 11. Field/Pool McArthur Rlver 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 15,095'feet lO,230'feet ' 81 ' feet ' feet Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical ~ngth Size 364' 26" 560' 17 3/4" 6456' 13 3/8" 12,009' 9 5/8" 3197' 7" See Attached Tubing (size, grade, and measured depth) 4 1/2", 12.6#, N-80 & Packers and SSSV (type and measured depth) Baker FB-1 11,250 13. Attachments Cemented Measureddepth ~ueve~icaldepth 364' 364' 675 sx 560' 560' 2825 sx 6456' 4443' 1000 sx 12009' 10227' 600 sx 15091' 3 1/2", 9.2#, N-80 ~ 11,339 '. SSSV' Otis $ 322' Descriptio~h summary of proposal ~ Detailed operations program BOP sketch __ 14. Estimated date for commencing operation · ~15. Status of well classification as: February 6, 16. If proposal was verbally approved Oil ,t- Gas ~ Suspended __ Name of approver Date approved ! Service 17. I hereby ce);tij'y that the foregoin~ is true and correct to the best of my knowledge. signed Roy Roloer itle Environmental Engineer Date //,./ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission ~" ' ' so representabve may w~tness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- ~' ~:~ '/ Apo,'oved Copy Returned 01131/89 ApprovalNo. f.. ~~ Approved by order of the Commissioner Commissioner _ Form 10-403 Rev 06/15/88 SU B/FlIT fN TRI PLICATE GRAYLING PLATFORM PERFORATION PROCEDURE . . . . ® . . . 10. 1i. RU Wireline unit. Pressure test lubricator to 2500 psi. Static bottom hole pressure is 4025 psi. Make necessary runs to pull ball valve, check minimum pass ID and tag for fill. RD Wireline unit. Conduct a safety meeting with the platform foreman and service personnel. The service company personnel will review the procedures and provide a diagram of each tool to enter the well. This may be facilitated by completion of the tool string description on the Unocal wireline report. After completion of the job, and prior to release of the service personnel, the wireline report is to be completed. RU E-line unit. Pressure test lubricator to 2500 psi with FIW. Pressure testing with gas with guns in the lubricator may cause premature detonation. Prior to making up each gun and tool string, shut down all non-directional radio and microwave transmission. Notify helicopter pilots, etc. Shut down all platform welding. These may return to service after the tool string is 500 feet below the wellhead. RIH with perforating guns continuing with well shut in. When out of tail, limit travel rate to a maximum 40'/minute. Begin flowing well and tie in. Perforate intervals stated below. Shut well in and pull out of hole. Again confirm radio silence by making the proper announcements assuming live guns are being pulled from the well. Check guns and record depths not perforated due to misfires on t~e wireline report. Repeat 6, 7, 8 for each successive run. RD E-line unit. Bring well on slowly and obtain a stable proOuction test. Bench Perforation Interval Interval Footage HB - 1 HB - 1 HB - 2 HB - 3 HB - 3 HB - 3 11,373' - 11,382' MD DIL 11,382' - 11,412' MD DIL 11,432' - 11,512' MD DIL 11,520' - 11,535' MD DIL 11,535' - 11,570' MD DIL 11,570' - 11,595' MD DIL 9' (New) 30' 80' 15' (New) 35' 25' (New) 194' O019n/lll TBUS 6-17RD GLM GLI~ O L...__.j- ,,I 8 GLMi I0 ' !! ' · McARTHUR .RIVER FIELD ' CASING DE TAll ~ 26" CASING ~.T 364' ~ 17 3t4", SPIRAL,WELD, AT 56,0' (Crnf'd W/675 SX5) 3;Z: [3 5/8",6¢¢~, J-55, BUTT.,AT 5978:(W~NDOW 3978'- 4039') Cmt'd W/2500 SXS, RETAINER AT VT TOP ,7,",29 .~,N-80,BUTT. AT 9655' (Cmt'd W/4L>OSXS} Trr~ 9 5/B ',47¢, N-BOEt S-95,BLITT., AT i0,~62' (Cml'el W/3075 sxsI T13T BOTTOM 7 LINER, BAKER FLOAT SHOE AT TUBIN TA I1 4 112", 12_..6'¢' & · ;5 112",9.2''¢, N-BO., BUTTRESS TBG. I 4 I/2" OTIS B,A, LL VALVE AT 521.85' 2-8 4 112" CAMCO MMG" GAS LIFT MANDRELS AT: 2)2543.71' 3) 5254.80,'~4)6761.26'~ 5) 7746.37 '~6) 8489.96'~ 7 ) 8972 8) 9324.41 9. CROSS'OVER 31/2" X 4 112" 10'15 3 I/2" CAMCO "MMG" GAS LIFT MANDRELS AT 9960.55'i 12)10~275'~ 13)10,596'it4) 10,911' ~ 15) II, 170' 16. 51/2" OTIS "XA" SLEEVE AT 11,:>09' I?. BAKER LOCATOR SUE a I/4"X 3" I.D(LANED 2.16' OFF PKR.)'I1,245' 18 BAKER SEAL AeSY. 4"X 5" I.D.(LOWER SEAL MULE SHOED) FROM !(.245.84' TO 11,268.04 19 BAKER 7"×4",,MODEL FB-I PERM. PACKER SET D.P. 11,250' (W/5 I/2"X4 l/Z MILL OUT EXT · 11,255.63) PKR. AT 11~248.00' 20. ~I/2"X 55/4" CROSS OVER AT !1,Z74.75' :~I. 31/2"X 2.75"11D. OTIS X NIPPLE AT I IT507.88' 2.2. 5112"MULE SHOE AT il,339.05' P£F FOF A T/ON t £COPD DATE INTERV/~,L PRESENT CONDITION 2_/7/78 4114'- 4115' IS,~LATI~,N SOU~,EZE (w4.50 SXS) 2./7/78 4006'- 4007' (w/300 S×S) 5/2~8/78 it,582'-11,4iF' PRODUCTION BENCH I 3128/78 !1,452'- !i,512 PRODUCTION BENCH 2 ;5126178 11,535' 11~570' PRODUS, TION BENCH $ , ~ , T.B.U.S.G - t7 R D WELL · SCHEMATIC. UNION OIL COMPANY OF CALIF'ORNIA & ~,2~OR AGE WELL TBUS 1 -17 RD CASING & CEMENT DETAIL VOLUMES SHOWN ARE (CMT. VOL./HOLE VOL.). 26', 1° WALL, DRIVEN TO 364' 17 3/4 ',0.341" WALL, SPIRAL WELD CSG AT 560' 675sxs (776ft~/516ft~) TOP CMT, 622' NOTE 1. NOTE 2, 9 5/8' CSG STUB, 6200' PLUG, 300sxs 13 3/8',61+,J-55 CSG AT 6456' TOP CMT, 1677' MILLED WINDOW !N 13 3/8' CSG FROM 3978' TO 4039' CMT RET, 4 100' CMT RET, 61 SEE NOTE 1 SEE NOTE 2 · BTM PLUG, 649 , ~ 5/E':40,~,43.5+,& 47~:N-BO&P-110 CSG AT 12009' lO00sxs (1150ft /3991'ft ) CMT · 8549' TOP 7°,29~,N-80 LINER AT 9683' 9 5/8',47'~,N-80 CSG AT 10162' 3075sxs (3540ft"'/3323fl~) I 1950' ETD COMP. 3/5/69 7°,29~,N-80 AT 1214D'~ COMP. 3/28/78 , 42Dsxs (483tt~/31211'~ 7',29~,N-80 AT 15691' 600sxs (690tt-~/405ft~ · NOTE: ALL CMT TOP ARE THEORETICAL .... .--i, GRAYLING PLATFORM I ;j CASING & CEMENT DETAIL ; ',, ~ ' r, ~. "._' ,., ;' :..,, - ~.. - . :.' ,, . .:. _ i 4' 5K WKM ~°°~ ~:~ 0 PSI - 10' 5000+ J L 2' 5K (~) DCB FE GV CIW : GOOD ~ 12' 3000,~, 0 PSI ; 2' 3K ~CIW WF FE GV ClW BAD 12' 3000+ 50 PSI SHAFFER KD ~ 2' 3K i ~ SE BV CIW , 13 3/~' i 9 5/8' [ , -- WELL TBUS G'17 '. ~[ 712185 - ' GRAYLING PLATFORM LEG _ UN~ON O~L COMPANY OF CALiFO~N~A Document Transmittal Union Oil Company of C. at~fornia unlen DATE SU'E~MITTED ACCOUNTING M~)NTH Apr. 25/78 --TO FROM State Division of R.C. Warthen Oil & Gas AT AT 3001 Porcupine Drive California Anchorage, kK. 99504 2,0, BOX 6247 Attention: H. W. Kuq ~.o~ r ~ncnorage, ~. TRANSMITTING THE FOLLOWING: 99502 CONFIDENTI~ T~U G-17 1 Set Bluelines Plus 1 Set Sepias Directional Survey Final Logs G-17 RD D'.',';sior'; (:~ ~,, -~ ::...: L:,:~.~, ;".::,ion PL~E ACKNOWLEDGE ~CEIPT BY ~.~,;',~'~ AND ~TU~NING COPY OF FORM 1-2M02 (REV. 11-72) PRINTED IN U,S.A. Form P--7 SUBMIT IN Dt~PLIJATE* STATE OF ALASKA {See other in- structions on reverse side) OIL AND GAS CONSERVATION COMMITTEE i WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* b. TYPE OF COMPLETION: NEW ~] WORK [Z] DEEP- [~] PLUG [~] DIFF.Fa Redrill EN BACK RESVR. ~ Other OVER %VELL 2. NAME OF OPERATOR Union Oil Company of California ADDRESS OF OPERATOR Box 6247 Anchoraqe. Alaska 99502 LOCATION OF WELIJ- (Report location clearly and in accordance with any State requirements)* At,u~ac~ Conductor 23, Leg 4, 1832' N & 1488' W from SE corner Section 29, T9N, R13W, S.M. it to, ~ro¢ ~,t~r,al reporte~ belo~, Top of Hemlock 1798' N & 1505' W from At total depth .~O ~' ~ ~'>-~' SE corner Section 29, T9N, R13W, S.M. 5. API NU1ViEH/CAL CODE 50-133-20161-O1 6. LEASE DESIGNATION A3ND SERIAL NO. ADL - 17594 7. IF INDIA_N, ALLO~Iq'EE OR TRIBE NA1VIE 8. UNIT,FAR/Vi OR LEASE NAME Trading Bay Unit 9. WELL NO. TBUS G-17 RD(33-30) 10.FIELD A~D POOL, OR WILDCAT McArthur River - Hemlock 11. SEC., T., R,, M., (BOI'rOM HOI_~E OELIEC'rlVE) Section 30, T9N, R13W, S.M. 1882' N &/1658' W from SE corner =. PE~IT NO. Section('29, T9N, RI3W, S.M. 78-3 2-12-78 ] 3-16-78 [ 3-28-78 99' RT to MSL ~ I-]]OW1VISklNIY* ROTARY TOOLS CABLE TOOLS 10.163' TVF) [ 10,054' VD 3983' - 12,140' 22. PRODUCING INI~E3~VAL(S), OF THIS COMPI_2gTIOINT--TOP, BO'I'rOM, NA3VIE (MD AND 'I'V'I))* 23. ~VAS DIREC-'~rlONAL ! SURVEY MADE Top Hemlock 11,374' MD, 9,444' VD ! Yes Base of Hemlock Bench #3 11,600' MD, 9,655' VD i 24. TYPE ELECTRIC AND OTHER LOGS ,RUN Dil, Sonic, Gamma. Ray, Caliper, Neutron De,nsity~ Dipmeter . CASI3NTG RECOP, I) (Report all strings set in well) ]7 3/4I.' .312" wall...sPllral we d 560'_ I 22" I 675 sx none /3 3 8' - ' ,, r / .. [ 61# [ J--55 6456 [ [ 17 [ ?a?--~ ~X none *Note: [Window mill]ed in 3 3/8" .csq [3978.'-40~.9' 9 5/8" [ 47# I S-95:10,162' -[ 12 ~a non, e 26. , LINER lqsEC O~: ~,~-- 8 0 - / 27, TUBING -----7"' [ 9655' I 12.i"40' ! 42n _~× N/A t3½:' x 4%/' '11,272'" -I t [ I I ! 28. PER~ORATIONS OPFiN TO PRODIJC~iOlq (Interval, size and number) 29. -ACID, Si:lOT, FSkC~FURE, CEa~iE:NT SQUEEZE, ETC. Bench #l 11,382'-11,412' .34"hole 4hpf Bench #2 11,432'-11,512' .34"hole 4hpf ! ~,c,~.; Bench #3 11,535'-11,570' .34"hole 4hpf PI~ODUCTION DATE FIRST PRODUCTION I PI~ODUCTION ME'iI~OD (Flowh3g, gas lift, pumping~size and type of pump) 3-28-78 [ Gas Lift DATlc- OF TEST, II{OURS TESTED ']cT{el'iR SIZE [PROD'N FO'~ OI~B~L. G~CF. 3-29-78, ! 24 hrs. 13 17/64"] ~' I 3888 I370 ~, WBING ICA~mG P~SSU~ iCAL~~ OI~BBL. GAUZES. 0 I ~060 ] ; 'l 3888 I 370 31'. 'v~seos~io~ or a~s (8old, uaed lor ~uel, ~enteg, etc.) WATEr. BBL. ]OIL GRAVITY-API (CORR.) I 96 I .095 t TEST WITNESS~,D BY Mr. William Hess Sold 3~. ~xsT o~' 33 ' I ~ ~] · i herebY ce~ff~ that the~t6rdg~dP'g a~!~attached, lnforma~bn is complete and correct as determined from alYavallable records s,a**~:~*dlm ~. ca/lenaer ' ~tr~ District Drilling Supt. v**~: 4-6-78 ~1 i *(See Instructions and S~ces [or AdditiOnal Data on Reverse Side) unut-in) ', Producin~ WATEII-~BBL. I GAS-OIL ll?kTIO I 96 i .095 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log or'~ all types of lanJs and leases irt Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- merits given in cther spaces on this form and in arty attachments. Items 20, and 22:: If this well is completed for separate, production from more thar~ one interval zone (multiple co*r'npletion), so state ~n item 20, and in ite,~ 22 show tl'uz prc:]c~c'~r:!l intcrv~_~l, or ~nte~v,:~ls, top(s), bottom(s) and name (s) (if any) for only the intervut retx~rted ir~ item 30 Submit ~-~ separate report (page) on this form, adequately identified, for each additior~l ir~te~ val to be separately prod~ce:J, show- ing the odlditional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this .well shoulJ 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, SUMMAItY OF' FX)RMATI~)N '¥I~L~)'i',~ IN('I&II)IN{; I N'I']-:[tV~L 'I'F.~TEI). I)H~]SSUHE DATA ~ '~[C'OV~I{IF.~ ()F ()IL GAS 35 G~GIC WAT~[ AND MUD ,. NAM~ M~AS D~{ ~ V~RT~ D~I Top "B" Sand 4932' 3434' Top "C" Sand 5812' 4193' Top "D" Sand 6257' 459~' Top "E" Sand ~416' 6640' Top "F" Sand 9474' 7647' Top "G" Sand 10,603' 8723' Top Hemlock 1~ ,374' 9444' Top ~est [ocela~td 11,932 9967' 2~. CO.U.E DATA. Aq'rACII BRIEF D~R~[~ONS O? LITltOLOGY, PO:ROSITY, AN~ I)~rEc'rEl) SHOWS Or OIL, GAS Oil XVAT~t. .... "" UNION OIL CO. Oi':' CAL. ,, eA~r'_ £;EASE TRADING BAY UNIT STATEwELLNo G-17RD START DATE i-29-78__~COMP. D~T~'3/29/78 ffi~.LD McARTHUR RIVER COi...LR~CTOtl. PARKER ' --RIG NO.- LOCATION 1832'N & 1483'W of SE TYPEUNIT 1320 NATIONAL DIESEL ELECTRIC CORNER OF SECT 29 T9N RlllW SM DR!LLPi?EDESCRIPTION 5" E & S-135 19 1/2# ~LEVATiONS: WATER DEI~rH ~25' P$.~MIT NO. 68-108 'S~RI.M. NO._ADL 18730 R.T. TO OCEAN FLOOR 22~,, T.D. _I_2140'.TMD T.¥.D._lO162_T_V.D___ R.T. TO MLL~V DEVIATION (B.H.L.)5467 out @ N29°, 12"W R.T. TO DRILL DECK 1e~n, · R.T. TO P~ODUCTION' DEC~J a9 ~a ~ ~ - , , CASING g~ TUI3ING RECORD siZE I V/EIC-HT THREAD GRADE DEPTH REleARnS ~7 ~/~,q .... g.m~,, I _7'_' i 4 __29~/.f 4__1./2 x 12.6 3 1/2"[ q.2. Weld Butt Butt , Butt __Rl~tt . J-55 N ,-...80 &s 95~ N=80_._ N-80 _ 560 3978* 10162 12140 11339' ~ Cmt'd w/ 675 SXS Cmt'd w/ 2500 SXS. '13 3/8" window 3978-4039' Cmt'd w/ 3075 SXS Cmt!d_~_fLSXS., Li~er wZtop @ 9655' Taper String 1/2" x 3 ],/2" X-Over 0 g517' PERFORATING RECORD 2/7/78 ~-411.5' 4100 I~olatiOn ~q.~ SqzId w/ 150 SXS 4006-4007 4100i'Isolation So~ Soz'd w/ 3Z1D SXS .... ~8 11550-11570 12010 Production ' B~nch #3 ~3/26/78 11535-11550 12010 _~roduction Bench ~3 ...3/27/78 11462-11512 12iLLO Production Bench #2 ,, 3/28/78 11432-11462 120.10 Production Bench #2 3/28/78 11382-11412 12010 Production Bench #1 ...... I ,, , ,., . See attached for abandoned perf intervals .... l in original hole. INITIAL PRODUCTIO~T DATE IitTERVAL ' ~NET OIL ' CUT ~ 'GRAV. C.P. T.P. CHO%[E ,, . ~,tCF .GOB .I REJ~._3t!~ --3/3/78 HB#! thru #3 3373 2.2% 32 !/? ~n~n !!0[ 209 647 171 ' ,, · · , ,, · I WELL F~jND_A_S S E ~[ttL Y TYPE' CASING HEAD: 12I' 3000 psi 13 3/8" S.0.W. SHAFFER CASING HANGER: 12" x 9 5/8" SL'IPS CASING SPOOL: TUBING 'HEAD: TUBING HANGER: 12" 3000 psi x 12" 3000 psi 12" 3000 psi x 10" 5000 ·psi DCB Single 4 1/2" TUBING tIEAD TOP 4 1/2" EUE MASTER VALVES: Single 4' MASTER & SWAB CHRISTMAS TREE TOP CONN.: 4 1/2" EUE U ?,I i 0 ?q Oil_ CO. OF CAL. Ii'--O i",IIA 'WELL SHEET A PAGE biO. TRADING BAY UNIT STATE WELL NO. McArthur River LOCATION PEi-tMIT NO. · ,SERIAL NO. T.D.. T.V.D. DEVIATION (B.H.L.) COMPANY ENGINEER . SIZE j V!E[C-}tT j THnEAD G~ADE %3/4" Spiral Weld 13 3/8" 61# Seal Lock J-55 9 5/8" ,, 4 1/2_."-_ 3 1/2" 47,43,5&~0# Buttres 29~/ ! Buttress 9.2 &6.4 Buttress G-17 SPUD DATE COMP. DATE CO?,.rTRACTOR TYPE UNIT.. DRILL PiPE DESCRIPTION __ RIG NO. ELEVATIONS: WA. TER DEF]'it IL T. TO OCEAN FLOOR Il. T. TO MLLW Iq.. T. TO DPdI,L DECK R.T. TO PRODUCTION DECK APPROVED: e .......... ~ '--'~--~". - -'- _ - - ' ' CASING & TUBING ~ECORD P-110 N-80 N-80 DEPTH REMARKS 560 Cmt w/ 625 sx "G" 6456 Cmt w/ 2500 sx "G" 12009 15091 14276 See drilling record for details See drilling record for details Tubing PERFORATING RECORD ' 1 D~T_E J IILT~RVAL , F~T~D. . P~S_Q/L_ P~E~E~T CONDITLO_~I 3/5/69 1~298-14308 15025 Prnd~Jct~on ! ) 3/5/69 14330-14435 15025 Production ) _~ 5/7/69 14298-14308 15011 Injection ). Original hole abandoned. _[/3/69. 14350-14435 15011. ~_Injectio~ ) Perf!s sqz'd thru cmt ret 9/12/69 14455-14495 15011 I Injection ) @ 14000' with 300 SXS. 9/12'/69 14515-14690 15011' Injection ) 9 5/8" x 12 1/.4" sqz'd thru cmt ret. _9/12/69 14710-14890 15011 Injection ) @ 4100' w/ 150 SXS. prior to redril~.on ~{4/7 .9/12/69 14910-14990· 15011 Injection ) .Redrill on 2/4/78 2/7/7.~ 4114-4115 14000 Isolation S~: .2/7/78 4006-4007 4100 Isolation Sq: 13 3/8" window f/ 3978' to 4039' J 9 5/8" cut & pulled f/ ~'6200' . · - I ' INITIAL PRODUCTIO_~ DATE !HTE_RVAL NET OIL CUT ,,'GRAX;. C.P ...... T.P. [ CPfOKE BIC,,F GO1R .I RF~._BJg,,S .. , · . · . WELL IiE.~S SEMB LY TYPEL CASING HEAD: .... CASING HANGER: CASING SPOOL: TUBING HEAD: TUBING ItANGER: TUBING tlEAD TOP: MASTER VALVES: (" T ,r, .~t-IR.S. MAS TRI;E TOP CONN.: ~_-'~;~L TRADTNG BAY UNIT STATE ~.[i1 'i~, TBIlS G-17RD C~rln ..... , . , :,_~, McARTHUR RIVER SATE 1/29/78 1/30/78 1/31/78 2/1/78 2/2/78 15,095'TD 14,134'ETD (perm pkr) 13 3/8" cs @6456' 7" 1 iner @ 11,894' - 15,091' 15,095'TD 14,134'ETD (perm pkr) 13 3/8" cs @6456' 9 5/8" csg @12,009' 7" 1 iner @ 11,894' - 15,091' 15,095' 14,134' ETD (perm pkr) 13 3/8" cs @6456' 9 5/8" csg @12,009' 7" 1 iner @ 11,894' - 15,091' 15,095'TD 14,134'ET (perm pkr 13 3/8" c @6456' 9 5/8" cs @12,009' 7" liner 11,894'- 15,091' 15,095'TD 14,134'ET (perm pkr 1 3 3/8" c @6456' 9 5/8" cs @12,009' 7" liner 11,894'- 15,091' Commenced rig operations @12'O1 a.m. 1/29/78. Finished LD 3 1/2" x 5" DP (14 hrs). Moved Rig #55 over conductor 23 in leg room 4. Moved rotary table from Rig #54 to Rig #55 and continued general RU operations on Rig #55. · Finished installing rotary table on Rig #55, hooked up accumulator & service lines, connected electric lines and centinued general RU operations. Inspected and repaired as necessary (after 16 months shutdown) brake linkage, brake flanges, low drum clutch boot, air control valves and surface mud circulating system, Installed sand line and changed out drlg line. Worked on surface mud circ system and repaired low drum 'clutch. Cont. general RU operations. Finished RU operations on Rig #55. Loaded 4 1/2" tbg & 9 5/8" annulus w/ FIW. Installed BPV and removed 4 1/2" CIW X-mas tree. Installed and tested to Union specs 12" ~000 psi BOPE. PU on 4 1/2" x 3 1/2" tbg and worked tbg. @225,000# (80% of yeild on 4 1/2" tbg = 230,000#). Could not pull free from perm pkr @14,134' and 4 1/2" tbg parted @617' Pooh and LD tbg. All 4 1/2" tbg badly corroded insia~ and parted joint had hole extending 2 1/2" around jt in parted area. Ran 8 1/8" overshot w/ 4 1/2" grapple on 5" DP, incomplete. Finished RIH w/ overshot a~d engaged 4 1/2" tbg fish @617'. Ran Dialog free point indicator and found tbg 100% free @11,800' and 40% free @ seal assy locator sub @14,120'. Ran 2 3/4" od tbg cutter on W.L. and could not work deep6r than 5154' Ran 2 5/8" od tbg cutter on W.L. and could not work deepe~ than 6154'. Ran 2" od drfit on W.L. sinker bars and worked through tight spots @6154' and 4 1/2" x.3 1/2" X-over @1~.,.732'. Ran drift to locator @14,130'. Pulled 205,000# on tbg for back off and RIH w/ Dialog string shot to back off 3 1/2" tbg. String shot stopped @ X-over at 11,732'. PU on tbg to work string shot thru tight spot and tbg pulled free @190,000#. Pooh-and RD Dialog.~ Pooh and LD fishing tools and 4 1/2" tbg. Found holes in 4 1/2" tbg jts #67 (2120'), #212 (6700') & #230 (7270'). Holes corroded from inside of tbg - outside looks o.k. '._~':~ TRADING BAY UNIT STATE McARTHUR RIVER 6 2/3/78 7 2/4/78 8 2/5/78 9 2/6/78 l0 2/7/78 15,095'TD 11,770' ETD (cmt plug) 13 3/8" csg @6456' 9 5/8 csg 12,009' 15,095' TD 11,770' ETD (cmt plug) 13 3/8" csg @6456' 9:'5/8" csg 12,009' 15,095' TD 11,770' ETD (cmt plug) 13 3/8" csg @6456' 9 5/8" csg 12,009' 15,095' TD 6043' ETD (cmt plug) 13 3/8" csg @6456' 15,095' TD 4100' ETD (cmt ret) 13 3/8" csg @6456' Finished pooh and LD remainder of 4 1/2" & 3 1/2" tbg. RIH w/ 6" bit, 7" csg scraper, three 4 3/4" DC, 2260' 3 1/2" S-135 DP and 5" DP to 14,000'. Circ. hole clean and cleaned a'ctSve mud system. Pooh. Ran 7" Baker cmt ret on 3 1/2" x 5"' DP and set @14,000'. Pumped in Hemlock perfs 14,298'-14,990' @20 CFM & 1500 psi. Squeezed for abandonment-Hemlock perfs 14,298'-14,990' w/ 300 sx CL "G" cmt w/ .75% D-31, .3% D-19 & .1% D-6 mixed @ll8#/CF. Displaced 328 cu.ft. (345 total) below ret @ final pressure of 4850 psi. Pulled out of ret and dumped 17 cu;ft. (80') cmt plug on top of ret to 13,920'. Pulled up to 13,200' and spotted 50 bbl gelled - FIW pill. Pulled up to 12,200' and spotted for abandonment 100 sx C1 P,G" cmt w/ additives as above from 12,200'-11,770'. Po'6h and LD 3 1/2" DP and 5" S-135 DP. PU 12" 3000 psi BOPE and removed CIW 12" 3000 psi x 10" 5000 psi DCB tbg. spool. Removed 9 5/8" packoff an~l filled ' 9 5/8" x 13 3/8" annulus w/ FIW. Welded 9 5/8" slips to csg. NU 12" 3000 psi BOPE and tested to Union specs. Hole taking fluid @1950 psi while testing blind rams - no packoff on 9 5/8" slips and pumping in I3 3/8" x 9 5/8" annulus. Ran Tri-State 9 5/8" mech csg cutter on 5" DP and cut 9 5/8" csg @6200~. Pooh w/ DP. Ran Tri-State 9 5/8" csg spear w/ pack off and engaged 9 5/8" csg.::".Cir.c 9 5/8" csg and 9 5/8" x 13 3/8" annulus w/ FIW. PU 9 5/8" csg and knocked two welded sl,i.p segments, off csg. PU BOPE and removed slip segments. Finished NU 12" 3000 psi BOPE and tested to Union ~pecs. From cut @6200" pull.~d and LD 149 jts and 2 pieces (6166') 9 5/8" 40#, 43.5# & 47# N-80 Butt csg - cond. fair. Ran 12 1/4" bit and 13 3/8" csg scraper on 5" DP to 9 5/8" stub @6200' and circ hole clean. Pooh. Ran 13 3/8" Baker cmt ret on 5" DP and set @6100'. Pumped into formation below 13 3/8" shoe @6456' @20 CFM & 850 psi. Squeezed 9 5/8" stub @6200' and 13 3/8" shoe @6456' for abandonment w/ 300 sx C1 "~" w/ .75% D-31, .3% D-19 .1% D-6 and 10% sand mixed @llg#/CF. Final pressure 2000 psi w/ 331 CF cmt below ret. Pulled out of ret and dumped 49 CF (57') cmt on top of ret to 6043'. P.ooh and RU W.L. for gyro survey. RU Go Int. and ran Eastman gyro survey w/ CCL from 4500' to surface. Perf 4 holes @4114'-4115' using Go Int. 4" Densi jet "23" csg gun. Ran 13 3/8" Baker cmt ret. on W.L. & set @4100'. RD W.L. Ran stinger on 5" DP and stuhg into ret @4100' (4089' DPM). PI sqz perfs 4114'-4115' @ 15 CFM 1650 psi. Held 825 psi w/ pump off. Squeezed perfs 41t4'-4115' w/ 150 sx C1 ".G" w/ .75% D-31, .3% D-19~_..I~ D-6, 5% salt & 7% sand mixed @ 120#/CF to a final pressure of 1750 psi. CIP'@12:30 p.m. 2/7/78. Pulled out of ret and rev out from 4100'. Pooh and WOC 6 1/2 hrs. RU Go Int. and perf 2 holes ~40.Q6' using 4" Densi jet "23", csg gun. RD W.L. and RIH w/ 13"'3/8" Baker Fullbore retrievabl'e pkr to 3800'. WOC total of 11 1/2 hrs. o, I TRADING BAY UNIT STATE McARTHUR RIVER SATE ll 2/8/78 12 2/9/78 13 2/10/78 14 2/11/78 15 2/12/78 15,095' TD 41 00' PBTD (Cmt ret) 13 3/8" csg @ 6456' 15,095' TD 4100' ETD (cmt ret) 13 3/8" csg @6456' 15,095'TD 13 3/8" windo 3978' -4039' 15,09 5'-TD 13 3/8" window 3978'- 4039' 4188' TD 210' Footage 13 3/8,~ window 3978'- 4039' WOC total of 12 hrs after squeezing holes @4114'-4~15' to prepare for milling section. Finished RIH w/ 13 3/8" Baker FUllbore ret pkr on 5" DP and set pkr @3895'. PI squeeze perfs @4006' @ 8 CFM & 1550 psi. Held 900 psi w/ pump off. Squeezed perfs @4006' w/ 300 sx C1 "G" cmt w/ .75% D-31, .3% D-19, .1% D-6, 5# salt & 10% sand mixed @ 120#/CF to a final pressure of 2000 psi. CIP @2-30 a.m. Released pressure w/ no flowback. Pooh>and WOC 12 hrs. Ran 12 1/4" bit on 5" DP .and drilled out hard cmt from 3958' to 4082'. Circ hole clean and displaced. hole w/ FIW containing prehydrated gel for 70 vis. Pooh for CBL log. ' Finished pooh. RU Go Int. and ran CBL from 4090'. to 3600' indicating top of squeeze cmt @3892' and good bond across proposed window. Ran 13 3/8" Servco section m~ll and three~ 8" DC's on 5" DP to 3964' (3978' DIL). Circ. and cond. mud for 70-80 vis. Cut 13 3/8" 61# J-55 csg @3978' and milled -from 3978' to 4022' in 13 1/2 hrs (3.26'/h~--~ .... Milling conditions: 10,000# weight, 70-80 RPM, 526 GPH, 69# mud, 70-85 vis. Circ. hole clea~..and pooh to change blades on mill. Finished pooh and changed knives on section mill. RIH w/ Servco 13 3/8" section'mill #2 on BHA #2 to top of 13 3/8" stub @4022' - no fill. Milled 13 3/8" section from 4022' to 4039' in 5 1/2 hrs (3.1'/hr). Total 13 3/8" window 3978'-4039'. Circ hole clean and swept hole w/ 50 bbl pill. of 125 vis mud. Pooh. RIH w/ 5" OEDP to 4055'. Pumped 400 cu ft. FIW and spotted 200 sx Cl "G" cmt w/ .75% D-31 and 7 1/~% sand, mixed @120#/CF from 4055'-3838'. Pulled'DP"to 3600' and squeezed 26~CF cmt into window to final pressure of 1000 psi. Bled pressure to 0 and rec 15 CF. CIP @ 4:30 p.m. 2/10/78. Displaced hole w/ FIW and cleaned mud system. Pooh w/ DP. Repaired brakes on drawworks and built mud volume for drlg while WOC 24 hrs. RIW w/ 12 1/4" bit on 5" DP & drlg hard cmt from 3730'-3983' (5' below top of window) in 3 hrs. Circ. hole clean, pooh and PU dyna drill assy. RIW w/ ~2 1/4" bit #3 & kick-off BHA #4 on 5" DP to 3953'. Washed out 30' fill to 3983' and swept hole w/ 50 bbls of 125 vis mud. RU Eastman steering tool on Go Int. W.L. and kicked-off 12 1/4" hole thru 13 3/8" window 3978"-4039'. Dyna drilled 12 1/4" hole from 3983' to 4125' oriented 900 left from high side. Chg circ system over to drlg mud after drlg past 13 3/8" stub @4039'. Pooh for BHA change. RIH w/ 12 1/4" bit #4 and BHA #5 on 5"' DP and reamed dyna drill hole from 3978'-4125'. Drlg 12 1/4" hole from ~125' to 4188'. TRADING BAY UNIT STATE McARTHUR RIVER 11 2/8/78 12 2/9/78 13 2/I0/78 14 2/11/78 15 2/12/78 15,095' TD 4100' PBTD (Cmt ret) 13 3/8" csg @ 6456' 15,095' TD 4100' ETD (cmt ret) 13 3/8" csg @6456' 15,095'TD 13 3/8" windo 3978' -4039' 15,095.'~D . 1 3 3/8" window 3978'- 4039' 4188' TD 210' Footage 13 3/8.~ window 3978'- 4039' j , .. I WOC total of 12 hrs after squeezing holes @4114'-~.115' to prepare for milling section. Finished RIH w/ 13 3/8" Baker Fullbore ret pkr on 5" DP and set pkr @3895'. PI squeeze perfs @4006' @ 8 CFM & 1550 psi. Held 900 psi w/ pump off. Squeezed .perfs @4006' w/ 300 sx C1 "G" cmt w/ .75% D-31, .3% D-19, .1% D-6, 5# salt & 10% sand mixed @ 120#/CF to a final pressure of 2000 psi. CIP @2:30 a.m. Released pressure w/ no flowback. Poohi'.and WOC 12 hrs. Ran 12 1/4" bit on 5" DP and drilled out hard cmt from 3958' to 4082' Circ hole clean and displaced. hole w/ FIW containing prehy~rated gel for 70 vis. Pooh for · . CBL 1 og. Finished pooh. RU Go Int. and ran CBL from 4090'-to 3600' indicating top of squeeze cmt @3892' and good bond across proposed window. Ran 13 3/8" Servco section m~ll and three 8" DC's on 5" DP to 3964' (3978' DIL). Circ. and cond. mud for 70-80 vis. Cut 13 3/8" 61# J-55 csg @3978' and milled .from 3978' to 4022' in 13 1/2 hrs (3.26'/hr). Milling conditions: 10,000# weight, 70-80 RPM, 526 GPH, 69# mud, 70-85 vis. Circ. hole clea~_and pooh to change blades on mill. Finished pooh and changed knives on section mill. RIH w/ Servco 13 3/8" section mill #2 on BHA #2 to top of 13 3/8" stub @4022' - no fill. Milled 13 3/8" section from 4022' to 4039' in 5 1/2 hrs (3.1'/hr). Total 13 3/8" window 3978'-4039'. Circ hole clean, and swept hole w/ 50 bbl pill. of 125 vis mud. Pooh. RIH w/ 5', OEDP to 4055'. Pumped 400 cu.ft. FIW and spotted 200 sx C1 "G" cmt w/ .75% D-31 and 7 1/2% sand, mixed @120#/CF from 4055'-3838'. Pulled'DP"to 3600' and squeezed 26.CF cmt into window to final pressure of 1000 psi. Bled pressure to 0 and rec 15-CF. CIP @ 4:30 p.m. 2/10/78. Displaced hole w/'FIW and cleaned mud system. Pooh w/ DP. Repaired brakes on drawworks and built mud volume for drlg while WOC 24 hrs. RIW w/ 12 1/4" bit on 5" DP & drlg hard cmt from 3730' 3983' (5' below top of window) in 3 hrs. Circ. hole clean, pooh and PU dyna drill assy. RIW w/ ]2 1/4" bit #3 & kick-off BHA #4 on 5" DP to 3953'. Washed, out 30' fill to 3983' and swept hole w/ 50 bbls of 125 vis mud. RU Eastman steering tool on Go Int. W.L. and kicked-off 12 1/4" hole thru 13 3/8" window 3978':4039'. Dyna drilled 12 1/4" hole from 3983' to 4125' oriented 90o left from high side. Chg circ I system over to drlg mud after drl~ ,p, ast 13 3/8" stub @40395,., Pooh for BHA change. RIH w/ 12 1 4 bit #4 and BHA #5 on ' DP and reamed dyna drill hole from 3978'-4125'. Drlg 12 1/4" hole from 4125' to 4188'. TRADING BAY UNIT STATE McARTHUR RIVER 16 2/13/78 17 2/14/7851 18 2/15/78 19 2/16/78 20 2/17/78 21 2/18/78 22 2/1 9/78 23 2/20/78 4801I TD 613' Footage 13 3t8" Window 3978' 4039' 5168' TD 367' Footage 13 3/8" wi ndow 3978'-4039' 5908' TD 740' Footage 13.,3/8", window 3978'-4039' 6054' TD 146' Footage 13 3/8" window 3978'-4039' 6436 'TD 382' Footag 13 3/8" window 3978' - 4039 6830'TD . 394' Footag~ 13 3/8" window 3978'-4039' 7231' TD 401' Footage 1 3 3/8" window 3978' -4039' 7660' TD 429' Footage 13 3/8" window 3978' -4039' ,, Drlg. & surveyed 12 1/4" hole from 4188 to 4404' w/ bit #4 & BHA #5. Pooh for BHA change to slow angle drop. RIH w/ bit #4 & BHA #6 on 5" DP. Drlg & surveyed 12 1/4" hole from 4404' to 4535'.' ?ooh for-'BHA change to slow angle drop. RIH w/ bit #5 & packed BHA #7 on 5" DP and reamed thru new 12.'1/4" hole from KOP @3983' to 4535'. Drlg & surveyed 12 1/4" hole from 4535' to 4801'. Drlg & surveyed 12 1/4" hole from 4801' to 5112' w/ bit #5 & locked BHA #7. Pooh for gyro. RU Go. Int. and ran Eastman gyro survey from 4720' to 3900'. Survey no good - tool not falling in open hole. Re-ran gyro from 5100' to 3900' logging up. Repaired rotary back brake while logging. .RIH w/ 12 1/4" bit #6 on BHA #8 and drlg & surveyed from 5112' to 5168'. Continued drlg & surveying 12 1/4" hole from 5168' to 5589' w/ bit #6 & BHA #8. Pooh for BHA change - angle not dropping. RIH · w/ 12 1/4" bit #7 & BHA #9 on 5" DP and washed 30' to bottom - no fill. Drlg & surveyed 12 1/4" hole from 5589' to 5908'. Pooh for dyna drill to turn course direction right. Finished pooh w/ bit #7. Ran 12 1/4" bit #8 and DD BHA #10 on 5" DP to 5900'. RU Eastman steering tool on Go Int. W.L. Oriented tool for max right turn and DD 12 1/4" hole from 5908' - 5987'. RD steering tool and pooh. Ran 12 1/4" bit #9 and follow-up BHA #9 on 5" DP and reamed DD hole 5908'-5987'. Drlg and surveyed 12 1/4" hol~ 5987'-6054'. 'Survey @6030' shows 140 right turn and 3 1/4v angle drop from DD and follow-up. ., Drlg & surveyed 12 1/4" hole from 6054' to 6391i w/ bit #9 and follow-up BHA #9. Pooh for DD to turn course right. Ran ~1'2 1/4" bit #10 & DD BHA #4 on 5" DP to 6385'. RU Eastman steering tool 'on Go Int. W.L. Oriented tool for.~nax, right turn and DD from 6391' to 6492'. Steering tool indicated ll°:,.~ight turn and 1/2° angle drop at end of DD run. RD steering tool and pooh. Ran 12 1/4" bit #11 & locked BHA #10 on 5" DP and reamed DD hole from 6391 to 6462'. Drlg & surveyed 12 1/4" hole from 6462' to 6830'. Pooh for new bit & BHA change. Tight spot on trip out 6344' to 6295' - worked thru @400,000#. Ran 12 1/4" bit #12 & BHA #11'on 5" DP and reamed thru tight spot 5554'-5604' then reamed 50' tight hole to btm. Drlg & surveyed 12 1/4" hole from 6830 to 7191'. Pooh for bit change. Ran 12 1/4" bit #13 & BHA #12 on 5" DP and washed and reamed 50' to btm - no fill. Drlg 12 1/4" hole from 7191' to 7231 Drlg & surveyed 12 1/4" hole from 7231' to 7522' w/ bit #13 & #12. Pooh for__new bit w/ tight spot @5910'. Ran 12 1/4" bit #14 & BHA #12 on 5" DP and reamed 60' to bottom. Drlg 12 1/4" hole from 7522' to 7660'. '-~ TRAnTNG RAY IINTT STATF . '-,.-:-. ,,.,, G-17RD , ~ .... McARTHUR RIVER 24 2/21/78 25 2/22/78 26 2/23/78 27 2/24/78 28 2/25/78 29 2/26/78 8136'TD 476' Footage 13 3/8" windo 3978'-4039' 8406' TD 270' Footage 13 3/8" wi ndow 3978' -4039' 8830'TD 424' Footage 13 3/8" wi ndow 3978' -4039' 9155' TD 325' Footage 12 3/8" window 3978'-4039' 9206'TD 51' Footage 13 3/8" window 3978' -4039' 9206'TD O' Footage 13 3/8" wi ndow 3978' -4039' Drlg. & surveyed 12 1/4" hole from 7660' to 8049' w/ bit #14 & BHA #12. Pooh for bit & BHA.change. Ran 12 1/4" bit #15 & BHA #11 on 5" DP and washed 60' to btm - no fill. Drlg. from 8049' to 81 36'. Drlg. & surveyed 12 1/4" hole from 8136' to 8276' w/ bit #15 & BHA #11.. Pooh for new bit & BHA change. Ran 12 1/4" bit #16 & BHA #13 on 5" DP and washed 60' to btm - no fill. No hole problems on trip. Drlg. from 8276'-8406'. Drlg. & surveyed 12 1/4" hole from 8406' to 8602' w/ bit #16 & BHA #13. Pooh for new bit. Ran 12 1/4" bit #17 and BHA #14 on 5" DP and washed and reamed 60' to btm - no fill. Drlg. from 8602' -8830'. Drlg, & surveyed 12 1/4" hole from 8830' to 8905' w/ bit #17 & BHA #13. Pooh for new bit. RIH w/ 12 1/4" bit #18 & BHA #13 on 5" DP and reamed 60' to btm. Drlg. & surveyed from 8905' to 9155'. Pooh for DD to turn course left. Ran 12 1/4" bit #19 & DD BHA #4 to 9150'. RU Eastman steering tool on Dialog W.L. and oriented tool for left turn and slight angle build. DD 12 1/4~ hole from 9155' to 9206' in 7 hrs. Steering tool showing 8 left turn 1/20 angle build @ instrument (25' from btm). Pooh w/ DD and stuck pipe in keyseat w/ bit @429g' and top of 8" DC. @4166' Attempted to drive pipe down for 3 1/2'hrs. and 5" HWDP par~ed @4~90' (parted '@ btm of wear pad on'3rd it. abov~ DC). Pooh and LD 4 its. crooked_5" HWDP. Left in hole 12 1/4 bit, 7 3/4" DD, float sub, 2 1/2u bent sub, Eastman DOT sub, 3-8" monel DC, X-over sub, Jarco jars and 2 jt & 1 piece 5" HWDP. Total fish 209' w/ top of fish @4090'. Ran 10 5/8" overshot w/ 5" grapple, bumper sub, oil jars, 3-6 1/4" DC and 42 its 5" HWDP on 5" DP and engaged fish @4090'. (Note' 10 3/4" overshot will pass top of fish indicating min. id of open hole @4090' is 16"). Jarred down on fish for 8 hrs. w/o success. Mixed 80 bbls-of Oil Base Inc SFT {Black Magic) weighted to 70#/CF and spotted 40 bbls around end of fish @4299' - on spot @3:15 p.m. 2/26/78. Set string wt on fish and moved Black Magic 1 bbl each 1/2 hr for 4 hrs. Torqued pipe after 4 hrs and 5" HWDP parted @ btm of overshot grapple. Set pipe weight on fish and displaced remaining 32 bbl Black Magic to top of fish. Pooh and'rec 1.34' of 5" HWDP. New top of fish @4091'. Ran 10 5/.8" overshot w/ new 5" grapple, bumper sub, oil jars and 3-6 1/4" DC on 5" DP. ---'-~- TRADING BAY ~JNTT STATF ', .~.:_L ':S, G-17RD c:.-.; ~. McARTHUR RIVER 30 2/27/78 31 2/28/78 32 3/1/78 33 3/2/78 34 3/3/78 9206'TD O' Footage 13. 3/8" window 3978'-4039' 9206 'TD O' Footage 13 3/8" wi ndow 3978' -4039' 9206'TD O' Footage 13 3/8" window 3978' -4039' 9550'TD 344' Footage 13 3/8" window 3978'-4039' 9816'TD 266' Footage 10,079'- ETD - 9 5/8" csg F.C. 9 5/8" csg @10,162' 13 3/8" wi ndow i3978'-4039 Finished RIH w/ 10 5/8" overshot dressed w/ 5" grapple, bumper sub, oil jars, and 3-6 1/4" DC on 5" DP and engaged fish @4091'. Ran Dialog string shot and backed off @ top of 7" drilling jars included in fish. Pooh and rec. 2 jts & 1 piece (75') of 5" HWDP. New top of fish now @4166'. Ran 6 1/8" od screw-in sub, bUmper sub, oil jars, and 6-6 1/4" DC on 5" DP and tagged fish @4166'. Could not screw in fish - could tag top of fish w/o problem but screw-in sub walEing off 4 1/2" IF box on top of jars. Pooh. Ran 6 1/8" screw-in.sub w/ 10 5/8" x 3' skirt, bumper'~sub, oil jars and 6-6 1/4" DC on 5" DP to 4181' and u~able to tag'fish. (10 5/8" skirt on screw-in sub will pass' top of 8" DC by 15' -min hole id = 19" @4166'). Worked screw-in sub for 1 1/2 hrs w/o tagging fish. Pooh. Ran 6 1/8" screw-in .sub, 1-6 1/4" bent DC, bumper sub, oil jars, and 5-6 1/4" DC on 5" DP and tagged fish @4166'. Could not screw in fish - as before could tag fish repeatedly but could not screw in. Pooh and increased bend in 6 1/4" DC. Ran screw-in sub on assy as above and screwed into fish @4166'. Broke circ and circulated Black Magic out of hole. Circ and cond mud. PrepaPing to spot new Black Magic. Finished circ. hole clean and cond..mud after screwing in fish @4166'-4299' Mixed 80 bbl of Oil Base Inc SFT (Black Magic) weighted to ~O#/CF and spotted 40 bbl around bit @4299' - on spot @4:30 a.m. 2/28/78. Set 110,000# of string wt on fish and moved Black Magic 1 bbl each 1/2 hr for 4 hrs. Torqued pipe and moved Black Magic 1 bbl each hr'for~':next 8 hrs. Jarred down and torqued pipe each hr while moving Black Magic 1 bbl 'each 1 1/2 hrs next 4 1/2 hrs.- Fi'sh jarred down hole @7:00 p.m. Worked fish free and pulled thru tight hole from bit depths 4299' to 4050' in 3 1/2 hrs. Pooh w/ fish. FiniShed pooh and rec entire fish. LD fish and fishing tools. Ran 12 1/4" bit #20 on reaming BHA #7 including DOT jars and 30 its 5" HWDP to 13 3/8" window @3978'. Washed and reamed from 3978' to 4572' w/ two tight spots 4102'-4110' and 4425'-4430'. Circ and cond mud (5 1/2% oil after working Black Magic into system). RIH to 5500' and circ btms up. Pulled back into 13 3/8" csg @3978' w/ no problems. RIH & circ btms up 6600' & 7700,. Washed and reamed 250' to btm w/ 160' of tight hole on btm. Circ. and cond. mud. Finished circ. and cond. mud after reaming to btm. @9206' following fishing job. PoOh w/ 2 minor tight spots @4997' to 4430'. Ran 12 1/4" RR bit #20 on BHA #15, 30 jts. 5'.' HWDP and 5" DP to bridge @9000'. Washed out 2' bPidge and reamed 160' of tight hole to btm. Drlg & surveyed 12 1/4" hole from 9206' to 9550'. Pooh for new bit w/ 2 tight spots off btm @9330' & 9150'. No hole problems 4000' - 5000'. Ran 12 1/4" bit #21 on BHA #15. Reamed 100' to TD @9550', Drlg 12 1/4" hole to 9816'. Ran survey & pooh for bit change. Hole maintaining:strong tendency for right hand turn. TRADTNG BAY UNIT STATE '-'t "~ G-17RD c':i ~. McARTHUR RIVER 2AT=~ 35 36 37 38 39 4O 41 3/4/78 3/5/78 3/6/78 3/7/78 3/8/78 3/9/78 3/10/78 lO,167'TD 351' Footage lO,079'ETD - 9 5/8" csg F.C. 9 5/8" csg @10,162' 13 3/8" window 3978' -4039' lO,167'TD O' Footage lO,079'ETD - 9 5/8" csg F.C. 9 5/8" csg @10,162' 1 3 3/8" window 3978'-4039' 10,167'TD lO,079'ETD F.C. 9 5/8" csg @10,162' 1 3 3/8" wi ndow 3978'-4039' lO,340'TD 173' Footage 9 5/8" csg @10,162' 13 3/8" window 3978'-4039' 10,454'TD ll4' Footage 9 5/8" csg @10,162' 13 3/8" window 3978'-4039' 10,567' ll3' Footage 9 5/8" csg @10,162' 13 3/8" window 3978'-4039' IO,605'TD 38' Footage '9 5/8" csg .@10,162' 13 3/8" Windo~ 13978'-4039' t ! ! Ran 12 1/4" bit #22 on BHA #15. Reamed 90' to btm @9816' - no fill on btm. Hole cond. good. Drlg 12 1/4" hole to TD @10,167'. Ran survey - hole still turning to right. Made 30 std. wiper trip - hole cond. good. Circ & cond. mud to run 9 5/8" cs.~. Pooh w/ Bit #22. RU and ran 243 jts. of 9 5/8" 47# N-80 & S-95 Butt. csg and landed w/ shoe @10,162', F.C. @10,079'. Circ. well 3 1/2 hrs - o.k. Cemented 9 5/8" csg w/ 3075 sx. Cl "G" cmt. w/ .75% D-31, .3% D-19 & .1% D-6. Preceded cmt. w/ 400 cu. ft. FIW. Completed displacing 3075 sx Cl "G" cmt & bumped plug on F.C. @10,079'. Pressure tested csg. to 3550 psi - released pressure & float equip, held - o.k. PU 12" 3M BOPE & installed CIW 12" 3M x 12" 3M Type DCB csg. hd. spool & hung off 9 5/8" csg on CIW Type "CA" slips w/ 215M csg. wt. on slips. Tested csg. spool & packoff to 3000 psi - o.k. Reinstalled 12" 3M BOPE & tested to UOCO specs. Completed testing BOPE &-functioning lines to UOCO specs. Tested 9 5/8" csg to 3000 psi - o.k. TIH w/ 8 1/2" bit #23 on BHA #16 - rubbered every other it. of DP. Tagged F.C. @10,079' (10,071' DPM). Drlg F.C. & cmt. Retested 9 5/8" csg to 3000 psi - o.k. Drlg F.C. @10,162' '(10,154' DPFq). C.O. to TD @10,167'. Tested csg seat & Fm. to .65 psi/ft - held o.k. Drlg 8 1/2" hOle from 10,167' to 10,340'. Dropped survey & pooh. Rubbered DP every jt. for top 5000' of csg. TIH w/ Bit'#24 (Reed S-13GJ) oh BHA #16. Drlg 8 1/2" hole from 10,340' to 10,454' (114' in 6 3/4 hrs). Dropped survey. Pooh. Lost 3 cones off bit & worn down on shanks approx. 4". Ran 8 3/8" O.D. Tri-State junk mill w/ boot basket on BHA #17. TIH w/ 8 3/8" O.D.'Tr~-State Junk mill w/ boot basket on BHA #17. Washed thru bridge @10,283-10,285'. Milled on junk'@lO,454 - made 5' of hole w/ mill to 10,459'. Pooh. TIH w/ Bit #25 on BHA #18. Drlg & surveyed to 1~,567'. Pooh to PU D? lo turn course left. Pooh. PU DD on 2 1/2° Bent Sub BHA #19. Oriented DD for left' hand turn at TD 10,567'. DD to 10,605'. Pooh. Changed out electric motor on drawworks. TRADING BAY UNIT STATE ~'~.?; McARTHUR RIVER 42 3/1i/78 43 3/12/78 44 3/13/78 45 3/14/78 46 3/15/78 47 3/16/78 48 3/17/78 49 3/18/78 ]0,823'TD 218' Footage 9 .5/8" csg @10,162' 13 3/8" windo 3978'-4039' ll,ll5'TD 332' Footage 9 5/8" csg @10,162' 13 3/8" windo 3978'-4039' ll ,417'TD 262' Footage 9 5/8" csg 10,162' 13 3/8" windo 3978'-4039" ll,724'TD 307' Footage 9 5/8" csg @10,162' 13 3/8" windo 3978'-4O39' 11,964'TD 240' Footage 9 5/8" csg @10,162' 13 3/8" windov 3978'-4039' Footage 9 5/8" csg @10,162' 3 3/8" windot ]978'-4039' 12,140lTD 12,010'ETD plug catcher 9 5/8" csg @10,162 7', 1 iner 9655'-12,140' 12,140'TD 12,010'ETD (plug catcher '~9 5/8" csg i@10,162 '7" 1 iner 19655'-12,140' Ran Bit #27 on BHA #20. Reamed DD run & drlg to 10,756'. Pooh. Ran Bit #28 on BHA #21. Drlg to 10,823'. Drgl 10,823' - 10,916. Ran survey & unable to recover survey tool on W.L. Pooh. Ran Bit #29 on BHA #21. Dr!g to 11,155'. Repaired blower on rotary,motor. Drl.g from 11,155' to 11,417' w/ bit #29 on BHA #21. Completed TIH w/ Bit #30 on BHA #21. Drlg to 11,537". Lost pump press. Pooh. Located washout in S-135 DP @1590'. (Washed out in upset immediately above pin end). Trip back to btm @11,537'. Drlg to 11,724'. Pooh for bit trip - hole cond. good. Completed pooh. TIH w/ Bit #31 on BHA #21. Drlg & survey to 11,964 Drlg & surveyed from 11,964'-12,140'. Made short trip. Hole cond good. While going in hole after short trip manual override clutct) failed 10 stds off btm. Drqpped DP to rotary table and traveling block. RU to'circ DP. Restrung - PU block. 6 hrs required for repairs PU DP - DP free. Completed trip to btm. Circ. & cond. mud. Completed circ & cond mud to run logs. Pooh. RU Schlumberger & checked driller's TD of 12,140' @12,130' WLM. Ran DIL, GR-BHC-Sonic and Dipmeter from 12,130'WLM to 9 5/8" csg shoe @1.0,162'. Ran GR-CNL-FDC log from 12,130' WLM to top of 13 3/8" window @3978'. Removed hydromatic & overriding clutch assy on Rig #54 and installed on Rig #55 while logging. Ran 8 1/2" RR Bit #28 on BHA #21. Started reaming hole 150' off btm. Stuck DP @12,050' while reaming. Jarred DP dwn & jarred free in 1 hr. Circ & cond m~d @ TD 12,140' - lost pump press. Pooh. Had washout in S-135 DP @~tbp of pin ' end upset. I · '~:'-~-" ,,TRADING BAY UNIT STATE McARTHUR RIVER 2ATF_ t E7'5 50 3/19/78 51 3/20/78 52 3/21/78 53 54 12,140'TD 12,010'ETD (plug catcher 9 5/8" csg @10,162 7" 1 iner 9655'-12,140 12,140'TD 12,010'ETD (plug catcher 13 3/8" wind@ 3978'-4039' 9 5/8" csg @10,162' 7" 1 iner 9655'-12,1~0 12,140'TD 12,010'ETd (plug catcher 13 3/8" windoi 3978'-4039' 9 5/8" csg @10,162' 7" 1 iner @9655'-12,140 3/22/78 12,140'TD ll,250'ETD (perm pkr) 13 3/8" windo~ / 3978'-4039' 9 5/8" csg ~@10,162' 7" liner 09655 -12,140 3/23/78 112,140'TD 11,250'ETD 13 3/8" windo~ 3978'-4039' 0,162' liner 19655'-12,140' i 1 i ! 1 '/ Ran 58 jts (2484.84') 7" 29# N-80 Butt. Casing liner and TIW hanger and hung off w/ float shoe @12,140', F.C. @12,094', plug ) catcher @12,010', TIW hanger 9683', tie back sleeve @9655' Broke circ. & cir~. open hole capacity above top of 7" liner. P~mped 200 C.F. caustic water & 200 C.F. filtered water. Mixed 420 sx Cl "G" cmt w/ .75% D-31, .3%.D,19 & .1% D~6 (mixed @llS#/C.F.) Dipplaced cmt w/ drlg mud & bumped plug on plug catcher @12,010' w/ 3000 psi - held o.k. Released press, and floats held o.k. CIP @7:00 p.m. Pulled out of liner w/ no backflow and pooh . w/ tools. Ran 8 1/2" bit #29 on 5" DP to ooon' and WOC. WOC total of 12 hrs after 7" liner job. Finished RIH w/ 8 1/2" bit' 9 5/8" csg scraper & BHA #22 on 5" DP to 96hQ'. Washed 55' to top of 7" liner @9655' and found no cmt on top of liner. Close BOPE and pressure tested liner lap to 3000 psi (.884 grad) for 30 min- o.k. Pooh. Ran Baker 9 5/8', retrievamatic & stimulation valve on dry 5" DP and set pkr @9606'. Dry tested liner lap for 1 hr w/ no blow after 10 min - test o.k. Released pkr and rev. out 10 bbl mud entry. Reset pkr and pressure tested liner lap to 3000 ' psi - o.k. Pooh. Ran 6" bit, 7" csg scraper & BHA #23 on 3 1/2" S-135 x 5" DP to top of liner @9655'. Washed 100' ~.nto 7" liner and found no cmt in liner. Finished RIH w/ 6" bit, 7" csg scraper and BHA #23 on 3 1/2" x 5" DP and tagged cmt in 7" liner @11,979'. Drilled out cmt to plug catcher @12,010' and displaced hole w/ FIW. Pooh. Ran Eastman Gyro survey on Dialog W.L. from 12,000' to 4600'. Ran DA CBL- Signature log on DA W.L. from 12,010' to 10,000'. Signature camera failed. Re-ran log arid camera failed again. Repaired camera and re-ran CBL. Finished re-running D.A. CBL-Signature log from 12,010'.-9655'. RD D.A. PU Baker 7" x 4" Model FB-1 perm. pkr w/ 6' mill@ut extension, 18' seal bore extension, 1 jt 3 1/2" N-80 butt tbg, 3 1/2" Otiz "X" nipple (2.75" id), 1 jt 3 1/2" N-80 butt tbg and 3 1/2" W.L. guide - total 91.63'.pkr and tail. -Ran pkr on 3 1/2" x 5" DP and set @11,250' in 7" liner w/ tail @11,341' Pooh. Changed rams in BOPE and tested to Union specs. RU a~d ran Baker Model G locator w/ 2r1' of seals on 3 1/2" x 4 1/2" tbg and accessories. ~ Finished running 56 its (1744') 3 1/2" tbg & 311 jts (9491') 4 1/2" tbg and spac. ed out in Baker 7" Model FB-1 perm pkr @11,25'0 Landed tbg on CIW DCB hanger w/ end of tbg @11 272'. Baker 3. 1/2" Model G locator seal assy (w/ 20' of seals) @1i,248' Otis 3 1/2" "XA" sleeve @11,212, 3 1/2" x 4 1/2" X-over @9526', 4 1/2" Otis ball valve @299', w/ total of' 6-3 1/2" Camco GL mandrels & 6-4 1/2" Camco G1 mandrels. Removed BOPE. Installed & tested to 3000 psi C~W 4 1/2" 3000 psi double valve single block X-mas tree. Gas lifted out 703 bbl FIW to obtai'n differential for inflow perforating~ Ran 20' of DA .2.6" od steel carrier tbg gun and stopped @seal assy muieshoe @11,272'. Could not work deeper. .Muleshoe~possibly damaged when working sea,1 ~.~sy into p',(: to space out. Pooh w/ perf gun and ran 2 11/16' od blind box on WL and could not work through 2.75" id Otis "XA" sleeve @11,212'. TRADING BAY UNIT STATF. ,Itl "~ c'F;~ McARTHUR RIVER ..,._z_ .,,, G-17RD . ~ 55 3/24/78 56 3/25/78 57 3/26/78 58 3/27/78 59 3/28/78 12,140'TD ll ,250' ETD (perm pkr) 13 3/8" windc 3978'-4039' 9 5/8" csg @10,162' 7'I 1 inet @9655-12,140' 12,140'TD ll ,250' ETD (perm pkr) 13 3/8" windo' 3978'-4039' 9 5/8" csg @10,162' 7" 1 iner @9655-12,140' 12,140'TD ll ,250'ETD (perm pkr) 13 3/8" windo' 3978'-4039' 9 5/8" csg @10,162' 7" 1 iner @9655'-12,140 I12,140'TD ll ,250'ETD (perm pkr) 13 3/8" windo~ 3978'-4039' 9 5/8" csg 910,162' 7" 1 iner 99655'-12,140 2,140'TD 1,250' ETD perm pkr) 3 3/8" window ;978'-4039' 9 5/8" csg @10,162' 7" 1 iner '~9655'12,140' I / Pooh. Ran 2 9/16" od blind box on WL and jarred through muleshoe @11,272' in 1/2 hr then ran through end of pkr tail ~11 341' Worked 2 9/16" blind box through muleshoe @11,272' for ~ hr ~/o w hangi~ up. Pooh w/ blind box. Ran 20' of DA 2.6" od steel carrier tbg gun and stuck in muleshoe ~11,272'. Worked free in 1/4 hr and pooh. RD WL..Loaded hole w/ FIW & installed BPV. Removed X-mas tree and installed BOPE. Tested BOPE to Union specs. Pulled seal assy out of perm pkr and circ hole w/ FIW. Pooh w/ 3 1/2" x 4 1/2" tbg. TBG muleshoe (3.9" od x 3" id) had'l" wide metal sliver bent toward center. Removed Baker muleshoe and welder muleshoe'd bottom seal ext. Ran and landed 3 1/2" x 4 1/2" tbg and accessories as before. Removed BOPE. Installed and tested X-mas tree to Union Specs. Gas lifted out 650 bbls FIW to obtain differential for inflo perforating. Inflow perforated lower 20' of Hemlock Bench 3 w/ 4'HPF @11,550' - 11,570' using DA 2.6" od Slim-Kone tbg gun. Tested perfs on GL for 8 hrs w/ oil to surface in 2 1/2 hrs and stabilized rate after 8 hrs of 672/383 BPD (cut 43%). Inflow perforated remainder of Bench 3 w/ 4 HPF ~ll,550~-ll,S7~' u~i~'~; ~A 2.6" od Slim-Kone tbg gun. Tested perfs on GL for 8 hrs w/ oil to surface in 2 1/2 hrs and stabilized rate after 8 hrs of 672/383 BPD (cut 43%). Inflow Perforated remainder Qf Bench 3 w/ 4 HPF 11,535'-11,550' using DA 2.6" od tbg gun. Tested perfs on GL for 8 1/2 hrs @ final stabilized rate of 1104/883 BPD (cut 2~%). SI to run in BHP bombs. LD 5" & 3 1/2" DP while flowing well. Finished RIH w/ BHP bombs on Camco W.L. and hung bombs @ 11,336'. G.L. well for 2 hrs to stabilize rate @1F108/827 (18% cut). Shut in 6 hrs for BHP build up beginning @ 4:00 a.m. Pulled bomh~ and RD Camco. G.L. well to obtain drawdown for perf. RU D.A. and inflow perforated Hemlock Bench 2 w/ 4 HPF 11,482'-11,512' using 2.6'-' od Slim-Kone tbg. gun. G.L. to clean up well for 20 min. and pulled gun into Otis "X" nipple @11,308'. Gun hung 8' into "X" nipple but pulled free in 2 1/2 hfs w/ 5750# (3000# above line wt). Pooh w/ 3(1' gun and found approx. 15 splits in gun but no swelling above 2 5/8". G.L. well for 1 1/4 hrs to cl6an up perforating debris. Inflow perf. Hemlock Bench 2 w/ 4 HPF 11,462-11,482'. G.L. well for 45 min. and pooh w/ gun noting minor drag in "XA" sleeve @11,209'. Finished inflow perf Hemleck Bench 2 w/ 4 HPF 11,432'-11,462' in two runs w/ D.A. 2.6" od Slim-Kone tbg gun~ G.L. well for 4 1/2 hrs @ final stabilized rate of 3936/3779 BPD, cut 4% from Bench 3 perfs 11,535'-11,570' and Bench 2 perfs 11,432'-11,5i2'. Inflow perf Hemlock Bench 1 w/ 4 HPF 11,382'-11,412' in two runs w/ D.A. 2.6" od Slim-Kone tbg gun. G.L. well to clean up perf'debris then shut-in 3 hfs to repair X-mas tree swab valve. ~Return well to G.L. production @11'00 p.m. and released rig from TBUS G-17RD @12:00 mid. 3/28/78. 11 TRADING BAY UNIT STATE '.~TI ;:0 G-17RD FTF.!~ McARTHUR RIVER SATE 3/29/78 ET] 12,140'TD ll ,250'ETD (perm pkr) 13 3/8" windo' @3978' -4039' 9 5/8" csg @10,162' 7" 1 iner @9655'-12,140 F~ETA[LS CF S?E.---..',T[,.,,a ...... . ......... Stabilized G.L. production rate after 24 hrs 3984/3888 BPD cut 2.4% from Hemlock Benches 1-3 perfs 11,382'-11,412', 11,432'- 11,512' ll 535'-11 570-' FINAL REPORT · PAGE OIL = CAL!FOPCIIA -!_51SE TRADING BAY UNIT STATE i~0, G-17RD FI =LD McARTHUR RIVER AFE: 381404 3/20/78 DATE ETD DETAILS OF OP~_r~TI~i,S, DESCRIPTIOilS g RESULTS TOTAL JTS: JTS 11 44 58 JTS 34 206 GRAYLING TBUS - 7" LINER 29# N-80 BUTTRESS T & C DESCRIPTION LENGTH BOTTOM Baker Float Shoe 7" 29# N-80 csg Baker Flat Collar 7" 29# N-80 csg T.I.W. Plug Catcher 7" 29# N-80 csg 7" 29# N-80 Pup Jt. 7" 29# N-80 csg 7" X-Over 7" x 9 5/8" T.I.W. Hanger 7" 29# N-80JPup Jt. 7" T.I.W. Tie Back Sleeve 8.13" OD 7,380 ID 3.35 41.20 1.77 83.06 1.00 462.99 14.38 1844.29 1.00 5.10 20.50 7.20 12140.00 12137.65 12096.45 12094.68 12011.62 12010.62 11547.63 11533.25 9688.96 9687.96 9682.86 9662.36 Centralizers 10' 30' & 60' from Shoe 1 on every other Jt to Hanger. ~"9 5/8" CSG DETAIL DESCRIPTION LENGTH BOTTOM Baker Float Shoe 9 5/8" 47# S-95 Buttress Baker Float Collar 9 5/8" 47# S-95 Buttress 9 5/8" 47# N-80 Buttress Lamped Below Zero 1.55' 89.15' 1.61' 1407.02' 8628.68' 34.30 10162.31' 10160.76' 10071.61' 10070.00' 8628,B8' 34.30 TOP 12137.65 12096.45 12094.68 12011.62 12010.62 12547.63 11533.25 9688.96 9687.96 9682.86 9662.36 9655.16 TOP 10160,76' 10071.61' 10070.00' 8662.98' 34.30' --0-- PAGE 'D ~ 0IL Ca-, A]N G" CALIFOB'IIA I,ELL BAY UNIT STATE AFE: 381404 3/23/78 l'i~LS ~I0, G-17RD FIELD McARTHUR RIVER DETATLS OF OPEP~%Ti~'~'~ DESCRIPTIC~IS g R~_,~ULTS JTS 10 10 10 10 11 16 24 32 TUBING DETAIL DESCRIPTION LENGTH 3 1/2" Mule Shoe .60 3 1/2" 9.2# N-80 Butt Tbg 31.15 3 1/2" Otis "X" Nipple 3 1/2" x 2.75 ID ..... 55 3 1/2" Buttress Tbg Collar .71 3 1/2" 9.2# N-80 Butt Tbg 31.19 3 1/2" x 5 3/4" X-Over .68 Baker 4" Seal Bore Ext. 5"x4" 9.69 Baker 4" Seal Bore Ext. 5"x4" 9.43 Baker Mill Out Ext. 5 1/2" x 4 1/2" Baker 7" x 4" Model FB-1 Perm Pkr set D.P. 11250' Tbg measure- ment 11,248.00' Baker S~ai Assy 4" x 3" ID Lower Seal Mule Shoed Baker Locator Sub 4 1/4" x 3" ID Landed 2.16' off Pkr. 3 1/2" 9.2# N-80 Buttress Tbg 3 1/2" Otis "XA" Sleeve 3 1/2" 9.2# N-80 Buttress Tbg #1 3 1.2" Camco "MMG" GL . Mandrel 3 1/2" 9.2# N-80 Buttress Tbg #2 3 1/2" Camco "MMG" G.L. Mandrel 3 1/2" 9.2# N-80 Buttress Tbg #3 3 1/2" Camco "MMG" G.L. Mandrel 3 1/2" 9.2# N-80 Buttress Tbg #4 3 1/2" Camco "MMG" G.L. Mandrel 3 1/2" 9.2# N-80 Buttress Tbg #5 3 1/2" Camco "MMG" G.L. Mandrel 3 1/2" 9.2# N-80 Buttress Tbg #6 3 1/2" Camco "~G" G.L. Mandrel 3 1/2" 9.'2# N-80 B~ttress X-Over '3 1/2" x 4 1/2" Butt 4 1/2" 12.6# N-80 Buttress Tbg #7 4 1/2"~'Camco "MMG" G.L. Mandrel 4 1/2" 12,6# N-80 Buttress Tbg #8 4 1/2" Camco "MMG" GL Mandrel 4 1/2" 12.6# N-80 Buttress Tbg #9 4 1/2" Camco "MMG" G.L. Mandrel 4 1/2" 12.6# N-80 Buttress Tbg #10 4 1/2" Camco "MMG" G.L'. Mandrel 4 1/2" 12.6# N-80 Buttress Tbg #11 4 1/2" Camco "MMG" G.L. Mandrel 5.29 2..34 22.20 .85 31.43 4.05 30.55 8.65 249.81 8.65 306.68 8.65 312.66 8.65 306.03 8.65 307.47 8.65 s .04 1.01 183.91 8.85 343.12 8.95 484.43 8.95 723.64 8.95 976.16 8.95 BOTTOM 11339.63 11339.03 11307.88 11307.33 11306.62 11275.43 11274.75 11265.06 11255.63 11250.34 11268.04 11245.84 11244.99 11213.56 11209.~1 11178.96 11170.31 10920.50 10911.85 10695.17 10596.52 10283.86 10275.21 9969.18 9960.53 9653.06 9644.41 9518.37 9517.27 9333.36 9324.41 8~81.29 8972.34 8487.91 8489.96 7755.32 7746.37 6770.21 TOP 11339.03 11307.88 11307.33 11306.62 11275.43 11274.75 11265.06 11255.63 11250.34 11243.00 11245.84 11244.99 11213.56 11209.51 11178.96 11170.31 10920.50 10911.85 10695.17 10596.52 10283.86 10275.21 9969.18 9960.53 9653.01 9644.41 9518.37 9517.27 9333.36 9324.41 8981.29 8972.34 8487.91 8489.96 7755.32 7746.37 6770.21 6761.26 D PAGE" OIL CF CALIFC?CIIA fLL ,LEASE TRADING BAY UNIT STATE l'i~Lk !I0, G- 17 RD FIELD McARTHUR RIVER DATE JTS 49 89 75 D~IA,_o OF OPEP. ATIONS DESCRIPTIOilS g RESULTS TUBING DETAIL CONTINUED DESCRIPTION LENGTH BOTTOM 4 1/2" 12.6# N-80 Buttress Tbg #12 4 1/2" Camco "MMG" GL Mandrel ..... 4 1/2" 12.6# N-80 Buttress TBG #13 4 1/2" Camco "MMG" GL Mandrel 4 1/2" 12.6# N-80 Buttress TBG 4 1/2" Otis Ball Valve 4 1/2" 12.6# N-80 Buttress Tbg 4 1/2" 12.6# N-80 Buttress Pup 3 4 1/2" Cameron DCB Tbg Hanger Elevatio~ TOP 8.95 5263.75 5254.80 2702.14 5254.80 2552.66 8.95 2552.66 2543.71 2219.41 2543.71 324.30 2.47 324.30 321.83 272.77 321.83 49.06 4.00 49.06 45.06 4.00 45.06 41.06 4..00 41.06 37.06 1.00 37.06 36.06 36.06 36.06 - 0 - Total 4 1/2" Tbg 311 Jt's 3 1/2" Tbg 56 Jt's 1497.51 6761.26 5263.75 TBUS' G-17RD 17 3/4" 560' Top of 13 3/8" Window @ 3978' 4 1/2" s'.v. 324 9 5/8" cUt & pulled F/6200' sqz'd w/300 sxs. Top 7" Liner 11894' 9 5/8" C. 12009 7" Cmt. ret. @ 14000' perfs sqz'd w/300 sxs. 7" L. 15091 'J TRADING BAY UNIT STATE G-17 R~ WELL SCHEMATIC Ltl~l. OZ'.~ O~ COMPAJ~IY OF C/d. IFORNIA 3 1/2" to 4 172" X- 9518' 3 1/2" "XA" 11213 7" Top 9655' ' 9 5/8".C. 10162 7" PKR 11250 3' 1/2" "X" 11307 3 1/2" M.S..1'1339 7" L. 12140 o~w~ ~R. LL_ C~:D. ~ .. BIT RECORD FILE NO. - 'SALESMAN: Page ., ' '" · R~ NO ~ ' ,,4.,/'- I ~O Z4~ ', . " · CONTRACT --.- · . - ~ .;:~,__' RIO MAKF COLLARS: OD X ID X LENGTH ' 'MO. '/ DAY / YR. T.P.-DRILLERS , FIE I~ 9 RIG SIZE . . , X X · SPUD L F ,," / ~ 5 WELL NO. (-'J~""'/ 7" f~ D PUMP NO. J. ,~'"'J/(~(") X X UNDER SURFACE ~/ /.~ . STAT /~,,~//~'~ COUNTY .. ,, PUMP NO. 2 ~'"// ~,(..~ DRILL PIPF UNDER INTER. / / WATER SOURCF ' T'SHIP/RANGE MUD TYP TOOL JOINT TOTAL DEPTH / / FUEL SOURCF ,,, ' , -,,. j ETS - 32nds FEET WT. Vet.I ,.~ PUMP PUMP NO I PUMP NO. 2 MUD PROPERTIES Dev. Dull-Cond. 1/4 V8 ' Date SIZE MAKE TYPE SERIALNo. ' Reg.1 2R or RO~ DEPTH OUT FEET HOURS PER HOURS CUM' 1000 R.P.M. pRESS. Liner SPM Liner SPM Wt.I~LF.V.P.V.Y.P. T, B G ........... · HOUR LBS. ' ,. ~ .:~ ,'~.:, ',, , , ,, . , ,.. ,.~'~ ,, ... ' - ' , ....... t,~.."~'/, '~,z// ,~,~,.r ~7Zj'? '~z ~ 7tqt 3~1~'q' ~,~.~ 79.5 ~'~ OD ;~..~ ~>' /~ ~ ~ . . , ........ ~ ' ' '' I , , , ,, .· . , ,, . ---- ,~ , ~./~ CONTRACTOR RIG NOL RIG'MAKF COLLARS: OD X ID X LENGTH ' · MO. / . DAY / YR. T.P.-DRILLER$ · .! COMPANY,' ...... FIELD RIG SIZF K.__X__ SPUD . STAT~ ..... COUNTY PUMP NO. 2 DRILL PIPE UNDER INTER. ~/ / ,,, WATER'SOURCE ,, s~c./ · T'SHIP/RANGE MUD TYPE. TOOL JOINT. TOTAL DEPTH ~/,, / FUEL SOUR~ ......... Ver. J JETS-32nds FEET WT. PUMP PUMP NO1 PUMP NO. 2 MUD PROPERTIES Dev. Dull. Cond. l~ 1/8 Dote RUN SiZE MAKE TYPE SERIAL Reg. R or RO DEPTH CUM. 1000 R.P.M. PRESS. NO. NO. 1 2 3 OUI FEET HOURS PER HOURS HOUR LBS. Liner SPM Liner SPM Wi. ~L. F.V. PN. Y.P T B G . . ...... . . . . :; '~ e' ' . t: ~.' : .... ' -- - - ~------'~'"'"' '~'Y ................. G . ' . .. .t. 4: · :, .-... Form No. SES 51 (Rev. 9165) : ]S Tr,_hcat_ Form. . .' '~: Fir',,'j ': .' ' L~ I: / ____~..*~-"~r~/~ I IN T..U U I( tJ K I I. I. I IN ' ' · ':?"'S ~:.,-.; -'.J/ t :~ .; · ., . ' ~ , . t. ~ . . , . . · . ' . ::. :; ' ,' . i .:~: ; . ' . CONTRACTOR- RIG NO.. RIG MAKF ......... COLLARS: OD X ID X LENGTH ' , .. " MO. / DAY / YR. T.P.-DRILLER$ .. CoMpANy. , FIELD RIG SIZE .. X - X - SPUD - . , ,/ -':; ,. .. , 'LEASE · WELL NO. ~"-~" j I ~ ~ PUMP NO. 1 X , .X__ UNDER SURFACE . · / /: , . STAIE~ . , COUNTY - PUMP NO. ~ DRILL PIRE UNDER INTER. / / WATER SOURCF.. SEC./ TOTAL DEPTH /_ / FUEL SOUR~ T'SHIP/RANGE " MUD TYPE TOOL JOINT. ~ ~, ' WT. PUMP >UMP NO 1 PUMP NO. 2 ~UD PROPERTIES Dev. Dull. Cond. l~ 1/8 , Date · JET5 - 32nd~ FEET CUM. 1000 R.~.~. PRESS. RUN SIZE MAKE TYPE SERIAL Reg. R or RD DEPTH FEET HOURS PER HOURS NO. NO. I 2 3 OUT ~OUR LBS. Liner SPM ,,~i~er SPM Wt.W.L.~F.~.P.V.'Y.P. T B G ,,. . ,, ~ , . ,, , . , . , , ., .., .... ., , _ , . . , , . . . . , .,. ,'.. ~ ,..."" ,. , ~ .'~ :.,~.~,'. ,. , . ~., ~.; - .. · , · ~. . , . ., ~ _, . -~ i , ,, , .... .. , ,; · .- , .,, ........ ~ . , , , . .,. ,, .... , ,. , .... ; ' ~, ~ ~' ~ ' ' '~': ,r ' ~ .... . . .... , . ....' : ' ,, . .- r' . .... 2:~- ~ ' . ~ '?' ' - .. -, .... ._~. ~ , i'.~' '" ': ' ::- ?~i' · ' " ,'? ,,~ .~',.~.. . : _ .. :.: . , }~:'[,i I ,, ;~ ~,i: ~' ;' ~. ; :,' Form No. SES 51 {Rev. 9/6~ .: ~,,~ INCORPORATED I P. O. BOX 22111 / HOUSTON, TEXAS 77027 ,~. retractor Pr'TR~6/~ PRIL/.I~/(;- OPERATOR.. PlVIo*.~ OIL. DRILLING com?,-INy of ¢.8. i..!~col~pJr~ MUD RECAP LEGAL DESCRIPTION.,, No. _. Gft~yu,UC,, l~..Rl'FoRm Rt6- ,55' Well Name And No. P, ilchem Milchem Yell No. Warehouse KEI4RI RLI~5IcA Field ?R~DI~& B~Y U~,T -(,o~< Z~L&'F COUNTY Cook .T~L~T Spud No. Drilling DATE T.D. TOTAL Date ~' 9-t975 DaysToT.D. 3~ REACHED-~'io°°J97e°_ DEPTH I'Z.l~O STATE TOTAL COST $ / P, CASING PROGRAM Depth (ft) Size (in) _ ~,~_.¢,.0_ i ~ ~ 7- BiTS No. Size (in) TYPE MUD SYSTEM Type .T.b;LET Depth Interval (ft) SOLIDS CONTROL EQUIPMENT Type Depth Interval (ft) ADDITIONAL INFORMATION Pump Specifications _~o '~/q X / ~ '" J Z V4~oL~ ~" VZ ;X ) D.P. and D.C. Other ,~"A?. & V,. ~.(. I ;}ATE J TIME DEPTH (ft) 193 :~ ) ., WTIl VlSCOSITYl(sec/qt) / VISCOSITY JJ POINT lb/100ft2)J (mi/30 min) Cake o J o / ,. JChloriae'' J Calcium' l(% bYJ(% byj(% byJ(% by J (me/mi I PPg) ~- I o lc @ j OF t(,b/i00ft2) 0/10 J pR J(32nd ~m I rf/'"f / (ppm) I (ppm) I Vo,.)IVo,.)i vo,.)lvo,.)l mud) I !1,37 i ._ 10 I% ~¢J/z ~.o ,o.o zG ,zoo '-~ ' Circ. Volume (bbl) REMARKS i Miichem Date _~-_~J=19._7.~_ Technical Representative . ¢Wllinrj Fluids Bi~isia, ' ING~I~PORATED / P. O. BOX 22111 ! HOUSTON, TE×AS 77027 .,:toC_~RK6R PRitcj~(.- OPERATOR I-/t~lo, DI iLLING k/iUD RECAP ·LEGAL oil cornP~t~y OJ: CrlL~,CoA~J¢I DESCRIPTION Well Name '~o._~f~ftyL/N[r ~LFiT~CoSrn f[l~,, _~5;' AndNo. 'rSU$ t'=~'/ R~P,~tk Field 7'RRD~6. I~Ry u,t~.r' COUNTY Cook .~LW'r- STATE~'~___.Z~_~;/.~/9 FUNNEL PLASTIC YIELD GELS FILTRATE Alkalinity FE TIME DEPTH WT VISCOSITY VISCOSITY Methy. Circ. (mi/30 man) Cake I ¢ Sand Solids Oil Water Blue Volume (ft) (ppg) (sec/qt) POINT (lb/100ft2) pHI / Chloride Calcium (% by (% by (% by (% by (me/mi REMARKS ~) /~l@I OF cp@ J°F (lb/100ft2) 0/10 I I (3:2nd Pm Pf Mf (bbl) __ APl HT-HP OF in) (ppm) (ppm) Vol.) Vol.) Vol.) Vol.} mud) ,,j~,, ,,~ .- # II %% %o o ~lfo! '2. ~. I/.~ Ioooo i.l / ~ ! !3/i,9 ~ %00 !87. 7..O =oo i 200 l ~oo I ~oo;I 100: I ' ~00 I ~oo I ,~oo'/ ~0 ~o Ioo Vg ! ~.o ..To il. z9 .s? i ~,4. 8' ~ooo .99 .$1 .97 /.ely :l.33 Milchem .ire ~'t.~ l~_1..~5~_~_~ Technical Representative _/.~' ~ District Reaion _C F} rJt~ D~ Eastman ~ ~'~ ~- Whipstock ~ A PETROLANE OOM~ REPORT of SUB-SURFACE DIREC TI ONA L SURVEY UNION OIL COMPANY OF CALIFORNIA COMPANY TRADING BAY UNIT G-17 RD WELL NAME COOK INLET LOCATI ON JOB NUMBER A178 GO227 A278 G0228 A378 GO284 TYPE OF SURVEY GYROSCOPIC GYROSCOPIC GyRoscoPIC SURVEY BY JEREMY BEATTIE EDWARD 'J. BUTLER OFFICE ALASKA DATE 2~8-78 2-13-78 3-21-78 LEastman Whipstock P. O. Box 4-1970~Anchorage, Alaska 99509/(907) 272-1032 TWX 910-881-5066/Cable: EASTCO March 28, 1978 Union Oil Company of California P.O. Box 6247 Anchorage, Alaska 99502 Well Number: G-17 RD - Location: Cook Inlet, Trading Bay Unit Type of Survey: Gyroscopic Dates: 2-8-78 2-13-78 3-21-78 Surveyors: Jeremy Beattie Edward J. Butler Job Numbers: A178 GO227 A278 GO228 A378 GO284 Atten: Jim Callender Dear Mr. Callender; I am enclosing the original and nine copies of the Gyroscopic surveys run on the above mentioned well. We wish to take this opportunity to thank you for calling on our services and ~trust that we may continue to serve you in the'future. Sincerely, Edward J. Butler Dist. Marketing Representative cc: file aRC. EJB/jab ..... ALL.__CALCUL~.ZI.ONS.._PERFORHED....~BY .I B. M._ ELE.¢TRONI.C CONPUTER TRUE ..J~EAS,_DR XET_V. ERT.~.CAL ..... SUB_j ....... DR..! FT ............ ?O?AL ...COORD..I.N~ES ................ ¢ L 0 _S_U._R_ E__5 ............. SEVER. IT.Y ........... $E¢ _)ON .... __DE~TH._ANGLE ...... DEPTH .................. SE,& ............. DIREC............................................. DISTANCE ................. ANGLE ...........DEG/ZOOFT _ DIS'lANCE D N DEG. D H $ I00 0 0 100,00 1.00 $79,00E 0,00 $ 0,00 W 0.00 $ 0 0 0 W 0.000 O. 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N. 59,00W ........6.~,~2 N 5~49,78 W 5~50,16 N 89 .... 19 21 W 0,886 5~50,0( ~_~D_6_O~_~. 0 99~,.~_~__~.~_~!~2 .~,~.8..~_00~ ......... ~5,..!~ N 5~67,28 W 5~6.~_~80 .... N....89_12 ~5 W 0,570 .CLOSURE 5520,5z+ FEET AT N $8 52 .... 5D N 5519.~+9 W 5520_,5~..._N._88_.5_2_53 W 0,OOO 552n,t5.9 W NAME ~..~T_ER_POLA_TED__._T. BU_E__V_EI~.I I.CAI., DEPTHS, COORDINATES._ AND _.CLOSURE,,S,_E,O,R .,GIVEN DEPTH$ MEA_.SU~E.~ ............ YE_~_? ICAL _~O.!AL ...... ~OORD INATE$ ................................ C ..... L__O__S_ U ~R E SUB DEPTH DEPTH DISTANCE ANGLE ....... D. ..... M ........ $ _ B .4_9.3~~3,~8~}.,,,9 l~---~._l.~.6~.,.A 2_$ ............ 307.5. 13__W~_..:~,018 ,.b l__S__87___16 ...... 2.5 .... 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N ................ 5~26,, ~.6~~.5~2.~, O0 __ N 8g g7 3~ ~B~ 11B9 2 ............ 9.929., 5! ............... 6.3,07 .... N ...... : ........ 5.4.~.~..,_~2 W' __ 5 ~4..~...,79 ..... N 89 .... 2.0 .... 11 ..... W ....... WF 1_.19..3_2 g.96_7_,_~ ............... .... 5~5.9,.11 W 5~5_g_,.5? ..... N 8g 15_.~.9_...W ---tVl EA $ U R E-D-- D E PTH--A ND-O. T H E R D A T A F 0 R. E V E R Y-EV EN 1_ 0 0--F E ET-.-.O F'---,S U B-,S E A.-.-D E P T H , .... . ,8_O__N ............... 0., ~_0 ..... E .................... /_7-_ O.,.S. ~..._N .......... L,. 23 w 1,5 9_S ............. .~_,_3~_._W_ ............................................. , ~llt $ ................ 16.,00__w. 10,79_$ ~0.,85 W ,6._z ..... $ ......... 1.2_2:_9..0_W 20,58 $ 1.77,8~+ W __138_1 151.1 1676 1.8..3_.8.. 2_0.1.0 ...................... 2 193 .... 2383_ 2.8.8.0 3.0A2 ~33_89_ ,,, ~53_2 33_6._~. 3_~.5_0. ~29 ~+693 __~_82_3 ~079 17_99., .......... 1..7. :00, ............... 39.~+_ ............................... 1.8_9..9.. ~ ......... 1.800, .......... ~ 8 ~ 9.0 1_9_9_9...,._ 19_00.., __565 8 2.0.9_9_.,._~.0_0_0... .... _6. ~ 6 o 2!~9_,.__21_ oo., ......... 6.e 1_ ................................ 22 99..,___z_Z.O.O_, ? ~+ 3 62 Z 3_9_.9., __23.0.0_., .81_ 2 ............................. e 9 2.~99_, 2 ~ 00_, ....... 89_. 0 78 25_~3 .__2 5 0,0_:__.9.. !3__ 83 2.6~8_, 2_6_0_0_,___1.062 8_9 2.7_9..9_. 2700.. ...... 1.._1_5.1 .............................. 89 2899. 2800. 1_230 79 2_9.~?_L_2_9_00.*___%288 ....... 5 e 3099, 3000, 1.332 3_!9_%,.___3.1..0. 0.., 136 ~+ ____32 3299. 3 200_.__1.39 z+ 30 3399, 3300, ..... 3/~ 99 .__3 ~_00..,_.___1._~ 2 35 9 9. ,3__5__0_0 ,' 1 ~..8.0 398~.7_,_$ .......... _8..0~_e.,B8 W ~0,62._$ 958,.83 ..... ~o.65.s ..... ~1.2~...8.7.__.~ 39,83_$ .......1..27!.,..7.~ .... 37,67 $ 1395897 W 3~.02 5 1515,~1 W 29,98 $ 16~2,87 W 25,16 S 1779,69 W ~9"O'e-S ...... 1_'9~-~-,-~ W ?e~6_$ .......... 2239.86.~._W ........... z ,_.1_ 1_ ._. s .... 2 s_99,? 8·~9 $ 2~8~ 28·12 5 2669·06 W 69.76 $ 95.~5._5 ....... 2932.66'W 30 ~22·98 S 301_0·22 W 28 150,~6 $ 3086,5~ W 28 1_76,2~ $ 31_62,06 W ............ NE~ SUB E.D.. ......... Y_E.B.T_!~A~ .... SUB MD.~_.T_..v,...D.._. .................... V.E_R..T_.[C_A L .... .____DE,P__T.t~ ........... _____~E~. $.E A.:,D~ 1E£E B,EIkCE ......... ,.C.OB~,B~.~.C,,.T~TL_O_N______,__T.O..T_A L_CQO,, R Di NATE$ .,5.203 :~6.9_9J .... 3.6001,__15 08_ 533 2 _.3!9.~ e ..... 3700.e ........................ 5819_ .............. ] ......... ~!~.~, ......... ~.100,__1.6_2.0.. ............................... 18 ........................... 326..,_3..~ ........... 3566 6.3.7 6~80 6691 6795 6899 7003 7109 7:32/+ 7~3_1 /+ 39 9, ..... ~_30.0., ....... 1.6.~.6 ................................... 12 :366,0!_$ .......... :366:3, ? 2 .... W ~.6.99, ...... .~_6P_o., .... 1675 e ................. ~P_~..,_~_O__S ............ 3.79~,_~_.W__ ..... ~799, 6700, 1681 6 ~09,10 S 3828,50 ~899, ~800, !.687 6 ~10,76 S ..... 3.8~..!~72 5099, 5000, ~696 ~ '~09,3~ S 3922,82 W 5199, 5~00, '1700 ~ ~Og,~5 ~ 3951,0] W~ 5399, 5300, 1710 6 ~10,75 $ ~016,87 W 5499, 5400, '1717 7 611,58 S ~05~,55 W ~ . 5599e 5~OOe 1725 8 ~11m~9 ~ ~093e77 W ........................... 5697,_..%60 o..,__ 1732 . 7 .... '7.64s ......... ~B99.,, ...... 580.0, .......... 1.7~ ..... 6 ....................... _4_0_~_:79 $ 4202. ................. - ~7A.7 ........................ 5999_, _5_9.00* .... _~_7~8 .............. "_ .... 4 401,.60_.5 ......... .8_05_9_ , 8.16~ 82_68 84.7_8 6_099, 6000, 1753 5 __8,9_8..3 .... 6_79~_, 6_7.00J__1_'7._8.~ ........... 8_6.88 .......... 5_8_89_,___6_8_ 0.0..,___ 13_ 89 ~ 6..999, 6900, 1794 a s 9 g ~ ,7 0 9 9_, 7 O_O_a, 18_0_0 .6199',__6 i_OQ, 1~57 6.29__9_, 6 20_0, 1760 63,9..~9_*,__6_3.00, 1.~ 6.~* 6_~.99, __6_._~.00- 1.7_6.9 ........................... 6.6.9_9_, .... 6600.,__117.9 397 ,_7.3___S. 381,26_5 .... ~3~,.~.6 W 3 73, 7 3_46,83._S ........ 3 3!,!9 _S ........ ~_~.9_9., O.l.~ 327,08 $ ~529,~1 W · , 315,7___.8_S , , ~, 5__.%9_'_._8../+ w ; .M, EA~URE ~-DEP-T-H-AND-D-THER-DA TA--FO EV ER¥--EVEN-1-00-F-EET-OF--SUB-SEA--DEPIH, ......................................... '_ ................................................................. PJ~P__~. T._R._HE ..................................................................... V E R T_I_~_A_L_S U B ......... M_ D_~ T.v_ D_ ........................ V.E R T. I_C._A. L ..... DEPTH .__S.~.A__.D_I..F_F E R EN C E CORRECT I ON T 0 T A L__~_O.O.~ D.! _N A..T_E5 ........ 9i.0~ _ ........ 7.29.9, ..... 7200, ......1.6.10 5 2.~i,.75 S.. ~61.9,09 W 92_!.3 7399, 7300, 1814 ~ 282,43._.5 ........... 4648,..8.0_ ~ ......................................................... 9318 7499, 7400e 1819 5 275,05 $ ~679,74 W 9423 7599, 7500, 1824 5 267,75 S 4.711,07 W 96.3...~ 7799., ........ _7...70.0., ...... !.83.5 .................................. 6 252,00 5 477~+, 37 W ~ ~. ?~._o.o., ..... 1.~.~_o ~_ .................. _z~_~...~.~'"'S.ii'i'_'_~'_80'~.'o.~"_-'_~/-~"_Ti: .......... ,~i.'/.T_.-_:'i'T'2"i"i'~i' ...... )": ...... 9843 7999, 7900, 1844 4 236,10 $ 4835,17 W 9948 80998 8000, 1849 5 228e00 S ~+865800 W ............... 3,0053 ................................... 8199, 8.!.00., ...... 1854 5 218,8/+ $ 4894,92 W 1...0..158 1036.8_.. 10473 LO_57,L !_0790 Lo_~9 7 8.2.9._9_, .... 8: 2..0_0.., .... !.8.59 ................. 8.3.9~.. ......... 8.3.00_.__!..863 4 19 7 ..5 8.....$ ........... ~.95.4..,..58 W 8.4.99 e .......... 8.4_.00, ........... 1.869 6 es~. 850~, !.e.~ .......................................... ~ ........... ?..!,O_~__s ....... ~oi. 3,_2~__~ 8_6_9_~_,__8.6~.P.,~ 87 9 5 155,30_..5 ......... 50~.2 · 19 W 8799_, ..... ~_.7_00.., ..... l_e.8 5 6 8899, 8800, 1891 6 124,54 S 5105,81 W ~. ~ ~ 00 ~!~..~.8__~- ....................... -~--' lo~. i e-' ..~'.'/,'s T-Ji'~ L.' ~ i~ o...0 ~"~ ......... w 9099, 9000, 1905 7 9199, 9100, 1912 7 .L~_2i9 1.1.3_2_6 11./+ 33 kl.Sb_O 11.6_~+_7 __1_1_7_5_3 9299. 9 2 00.,_._:L92 0 8 ~_3_99..,__73..0_0., ..... 1_9 2_7 ................................. _7.. 9.~9_9., 9 4:0 0., ........ 1.934. .................................. 7 %5_9.9_., 9.500, 1941 7 9_69_9_, 9_6Q0_,. .1948 7 9 799.,__~.~. O0, 1.~ .54. 6 9899, 9800, ;1961 ? 90,50 $ 5174,18 W 73.78 S ,5209,01 W 57,40 5 524.3,99 W 39,61 S 5278,29 W 20_, 35__S ...... 53_1.1.,_5!_._W 0_, 5.0. _.5_ ....... .5.3 ~_3...87__.W 1 9,.62_:N ...... _5._3_7_5 ,.3/+ W 39,24 N 54.06,58 W 57,60 N 54.37,8~+ W : I N T_~J~.O._LA_T_ED VA_JL_U_F,_S.__F_O_R.__. E~,E_N_._,I,.O.O.O__.F_EE.T_._OF__~E:__ASU..R_E..D._DEP T_H, D_EP TH _Y_E_R..T!~AL ............ _SUB ...................................................... __; .................. ~ DEPTH SEA TOTAL COORI~.INATES TD HORIZONTAL_ .:~VIE,W. · SCALE = I000' UNION OIL COMPANY OF :CALIF. TBU G-17 i TANGENTIAL AVERAGE' 'ANGLE .. i -- -i ........ { .. UNION OIL COMPANY OF CALIF. ................................................ tTBU G;'17-REDRILL ! 5600' 6000' i ' · ! . t 7600' [ . Unicm Oil Company of California State Pezmit No. 78-3 District ~ M~nager ~ion Oil ~y of ~if~rnia Box 6247 AD~ _a~e, ~ 99.502 Enclosed is the approved application for pennit to drill the ~ ref~ w~i1 at a location in Section 30, ~bip .qN, Range 13W, SM. A directional ~u%y rivers in Alaska and their dra/nage systems hav~ been classified as ~ for tP~ spawr~ng or migration of anadrcmx~s fish. Operati~s in these areas are subj~ to AS 16.50.870 and the regulaticms prcmulga~ thereunder (Title 5, Ala~ ~strative Code). Prior to c~ operatioDs you may be co.tatted by the Ha-q~itat Coordinator's office, DeparUm~t of Fish and C~m~. Pollution of any w~ters of ~h~ Stat~ is prdzibi~ by_ hq 46, Chapt~x 03, Article 7 and the regulaticms ~gated thereunder (Title 18, Alaska Adm~~a~ Code, Chap~ 70) a~nd by th~ Federal Water cc~ta~-t~d by a representative of the Department of En~tal tklr~t ~ AS 38.40, Local Hire Under State Le~s, the Alaska Department of Labor is behng notified of the issuance of this pennit to drill. To aid ~ in ~uling field work, we would appreciate your notifying this Office with/n 48 hours af~ the %~_11 is spudded. W~ would also like to be notified so that a re~tati~ of the Division m~y be present to witness testir~ of b~ p~ter equipment before surface casing shoe is drilled. T.B.U. G-17tH) (33-30) -2- January 6, 1978 event of suspensic~ or abandonment please give this office adequate ~ ~fication so tP~t w~ may have a witnmss present. Alaska Oil ~ Gas ~atic~ ~ttee Depa-~nt of Fi~ and ~, Habitat Section w/o encl. Department of Envi~tal Cc~~ation w/o encl. Department of ~, Supervisc~, Labor Law Ck~pliance Division w/o encl. Form 10-4-01' REV. 1-1-71 · SUBMIT IN TRIP 'E OIL AND GAS CONSERVATION COMMITT~" ~ i~B PERMIT TO DRILL OR DEEPEN' Oivi~o¢l DRILL ~ DEEPEN ~ la. TYPE OF WORK b. TYPE OF WELL WELLOIL [--] WELLGAS O OTItER I n j e C tO r SINGLEzoNE [X--] MULTIPLEzoNE L_jF-'! 2. NAME OF OPERATOR Union Oil Company of California 3. AI)DRESS OF OPERATOR Box 6247 Anchorage, Alaska 99502 4. LOCATION OF ~LL Conductor 23, Leg 4, 1832'N & 1488'W from SE Corner Atsufface Section 29' T9N, R13W, S.M. ^tpropo~dprod. zo,eTOp of Hemlock· 1900'N & 1600'W from SE Corner Section 30' T9N, R13W, S.M. 13. DISTANCE IN MILES AND D1RECrlON FROM NEAREST TOWN OR POST OFFICE* ! 28 miles N~,? of Kenai API No. 50-133-20161-01 I~' LEASE DESIGNATION. AND SERIAL NO. ADL - 17594 7. iF INDIAN, ALLOTTEE OR ~RIBE NAME 8. UNIT FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. TBUS G-17 RD (33-30) 10. FIELD AND POOL, OR WILDCAT gcArthur River - Hemlock 11.SEC., T., R., bi., (BOTTOM HOLE OBJECTIVE) Section 30, T9N, R13W, S.M. 12. 14. BOND INFORMATION: TYPE Statewides~etyandlo~No. United Pacific Insurance C°. B-55372 Amount $100,000 18. 21. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) 3,000' DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 1,600' ELEVATIONS (Show whether DF, RT, CR, etc.) 99' RI AbOve MSL 16. No. OF ACRES IN LEASE 5~116.00 19. PROP~)SED DEPTH 12,500 'TNB ( 10 ,'200 ' TVD) 17. NO,ACRES ASSIGNED TO THIS WELL 20. ROTARY OR CABLE TOOLS ROTARY 22. APPROX. DATE WORK WILL START JANUARY 1978 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HoLE SIZE OF CASING ~lG!~ PER FOOT GRADE SE~I~G DEPTH ~antity'of cement 12 1'/4,," 9'5/8, 47# N-80 f lOgO00' 1200 sx .. S-95 ,, , 8 1/2" 7" L " 29# N-80 9700'-12'500' 350 sx ........ PLAN OF PROCEDURE- · 2. 3. 4. 5. 6. 7. · Move rig over conductor 23 in leg room 4 and activate rig. Install BOPE as in diagram #1 & #2 and test to 3000 psi. Pull and lay down 4 1/2" X 3 1/2" injection tbg. Set 7" cmt ret @ + 14,000" and sqz for abandonment Hemlock perfs 14,298'-14,990'. Spot cmt abandonment plug from 12,200' to 11,770'. Cut and pull 9 5/8" csg from + 6400'. Set 13 3/8" cmt ret @ +_ 6350'-and sqz foc abandonment 9 5/8" stub and 13 3/8" csg shoe @ 6456' Mill section in 13 3/8" csg @ approximately 4000'. (cont. on pg. 2) IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on. present productive zone and proposed new productive zone. If pr0po~l is to drill or deepen directionally, give pertinent data on subsusface locations and measured and true vertical depths. Give blowout p~eventer pro.am. 24. I hereby c~tth~egoing ig T~- -- -- ..... d Correct ~ - 'Rober-t~,,,'/~i A~de~.~on., -. ~hJs space for State office use) ~NDITIONS OF APPROVAL, IF ANY: SAMPLES ~O CORE CHI~ REQUIRED [ MUD LOG ~HER REQUIREMENTS: ~ yES ~o [ ~ ~ES ~ SO Dm~XO~a~ SU~Y ~mum~ XV.L ~UMnmC~L CO~)~ ~ YES ~ NO Tn'LE Dist. Land Mgr. 50-133-20161-01 PERMIT NO. 78-3 APPROVAL DATE ,Imn~mr~z 6 1 q7R .<~~~ ~ ~~~a<~ ~{ember January 6 1978 APPOVED BY _ . TITLE DATE " ~ *See Instruction On Reverse Side ,"age For~rl REV. 1-1-71 SUBMIT IN TRIPI (Other instructim OIL AND GAS CONSERVATION COMMI't']~,i ~ ~ PERMIT TO DRILL OR DEEPEN TYPE OF WORK b. TYPE OF WELL OIL WELL [~] DR! LL E] GAS WELL E] 2. NAME OF OPERATOR OTHER DEEPEN n'] Aitcho~a~ SINGLE MULTIPLE r--I ZONE [~] ZONE L_J 3, ADDRESS OF OPERATOR 4. LOCATION OF WELL At surface SEE PAGE 1 6. LEASE DESIGNATION AND SERIAL NO. 7. IF INDIAN, ALLOTI'~E OR TRIBE NAME 8. UNIT FARbl OR LEASE NAME 9. WELL NO. TBUS G-17 10. FIELD AND POOL, OR WILDCAT 11. SEC., T., R., M., (BOTTOM tlOLE OBJECTIVE) At propoSed prod. zone 13. DISTANCE IN bI1LES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 12. 14. BOND INFORMATION: TYPE Surety and/or No. Amount 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig. unit, if any) 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, CONIPLETED, OR APPLIED FOR, FT, 16. No. OF ACRES IN LEASE 19. PROPOSED DEPTH 17. NO,ACRES ASSIGNED TO TtlIS WELL 20. ROTARY OR CABLE TOOLS 21. ELEVATIONS (Show whether DF, R'F, CR, etc.) 22. APPROX. DATE WORK WILL START 23. PROPOSED CASING AND CEMENTING PROGRAbl SIzE OF HOLE sIzE'oF'CASING "wEIGtIT PE'R FO6T ' GRADE SETTING DEPTH ' ' Quantity of cement _ . . · .... . .... · , , 9~ ll. 12. ~13. 14. 15. 16. Kick off and drill 12 1/4" directional hole on due West course dropping angle from 57o to 19©. Run & cmt 9 5/8" csg when hole conditions dictate, estimated @ +IO,O00'MD. Drill 8 1/2" directional hole to TD @ +_ 12,036' TMD (10,110' TVD). Log 8 1/2" hole and run cased hole porosity log to +_ 4000'. Run and cement 7" liner from +_ 9700' .to TD. Clean out liner and run CBL log. Perf and sqz as 'necessary for WSO in Hemlock. Clean out liner and test squeezes. Set 7" perm prod pkr and run injection tbg. Perf Hemlock and place on injection. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen ~ve data on present productive zone and proposed new productive zone. If proposal is to drill or deepen directionally, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout preventer program. · 24, I hereby certify that the Foregoing is True and Correct SIGNED DATE. , TITLE (This space for State office use) SAMPLES AND CORE CHIPS REQUIRED [] v~ [] NO DIRECTIONAL SURVEY REQUIRED [] YES [] N° MUD LOG [] YES CONDITIONS OF APPROVAL, IF ANY: OTHER REQUIREMENTS: [] NO A.P.I. NUMERICAL CODE PERMIT NO APPOVED BY APPROVAL DATE ..... TITLE *See Instruction On Reverse Side DATE DRILLING ,. ? ST, U¢O~RD 4 P.?£VE,'/T£'~ ,455E~I3L. Y NOTE· ALL CHANGES MUST HAVE WRITTEN APPROVAL BY TIlE DISTRICT SUPERINTENDEIIT. "'.: " "'-' BU££1_E . 'TP NK . - ' Or? ~,'n,/~' · · '~ . L.P. VJLVE POSInV£ CHOKE ,. DJUS / ^ ..,°L F CHO,~E ' I ! NOTE · ALL CHANGES MUST H.t, VE V,~iTTEN APPRO','AL BY 'TIDE DISTriCT . .. DR[L LI,',IG SUPERifITE i';DEt'IT. ' ·. ~0o0 p,~L b.~oc. .. -R 14W I WSHELL FU TO 11,160 l T 8 N 2000 TO 15 4ooo TD 11,767 K-II TD I 1,034 G-15 TD 12,885~ G-19 /~ T D 12,291 G-13 ID I 2, B.H.L: G-17RD 12,036' T M D---~- o 4 I0,1 I0' TVD ~"T/H£M' GRAYLING, I i~ 4'74' MD ~ 9,580' VD %..~ ID I0 G-5 sTD 10,312 TD I 1,38 I · -4 TD 11,772 G-4 T~, TD 10,t64 8 9 ~-? T t TD 11,072 9 -- %o 6 '" ,. "~6 9 TD]IO,400~ %~ ~ ~ ' TD,,,~ ~ /~ =~ ,o~ G-3 RDi~D'"u"~'° / ,~/u-~u Np D 7 ~6-23 ~T~,,,%, '"'~,o".~/~~'~,~o / / .' ~,~~ 9-29 / / S%~7 ~>~,..~D'-~~¢' - ' "¢',,/ ~ --~ ' DOLLY ~[ TRADING BAY U NIT ~ 5~1 G-17 ~D (33-30) 1,4 Iq77 D-15 TD I 1,905'~~I CHECK LIST FOP, [iEW WELL PERMITS Company .. ~FHtov~ .. Yes No Remarks 1. Is the permit fee attached ......... . .... · . ........ .~/~K Lease & Well Ho. 'T~,_L./. ~"~-/?AS°_Z~_ 2. Is well to be located in a defined pool ....... · ....... ~a~ 3. Is a registered survey plat attached ................ 4. Is well located proper distance from property line ........ /~ 5. Is well locai~ed proper distance from other wells .......... ~ ~ 6. Is sufficient undedicated acreage available in this pool ...... /~)C 7. Is well to be deviated ...................... X~ 8. Is operator the only affected party . .. .............. /~K~L~ 9. Can permit be approved before ten-day wait ............ /~ 10. Does operator have a bond in force ...... ; .......... ~/~ ll. Is a conservation order needed ................... 12. is administrative approval needed ................. 13. Is conductor string provided .................... 14. Is enough cement used to circulate on conductor and surface .... 15. Will cement tie in surface and intermediate or production strings 16. Will cement cover all known productive horizons .......... ~_~ 17. Will surface casing protect fresh water zones ........... ~ 18. Will all casing give adequate safety in collapse, tension & burst . ~__ 19. Does BOPE have sufficient pressure rating - Test to _~o00__ psig . ~ 20, Has DMEM approved Plan of Operation ............. Additional Requirements: Approval Recommended: Geol og~: Engi neeri ng: TRM JAL HHH ~ JCM ~ HWK /y'.~.~' LC~ RAD Revised 11/17/76
