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197-130
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS APR 2 2 2019 1. Operations Abandon LJ Plug Perforations L Fracture Stimulate U Pull Tubing J Operations shutdown Li Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change,Approved PlotJr@'m ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Dual GL Completion ❑✓ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development Q Exploratory ❑ Stratigraphic ❑ Service ❑ 197-130 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-10057-03-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADLOO18731 Trading Bay St A-03RD3 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Trading Bay Field / Middle Kenai B, C, D & E Oil Pools 11. Present Well Condition Summary: Total Depth measured 8,525 feet Plugs measured N/A feet true vertical 7,213 feet Junk measured N/A feet Effective Depth measured 8,343 feet Packer measured 308 feet true vertical 7,057 feet true vertical 308 feet Casing Length Size MD TVD Burst Collapse Structural 277' 20" 277' 277' Conductor 413' 16" 413' 413' 2,630 psi 1,020 psi Surface 1,871' 13-3/8" 1,871' 1,740' 3,090 psi 1,540 psi Intermediate 3,500' 9-5/8" 3,500' 3,045' 6,870 psi 4,760 psi Production 8,510' 7" 8,510' 7,200' 8,160 psi 7,020 psi Liner Perforation depth Measured depth 2,438-8,386 feet True Vertical depth 2,194 - 7,094 feet LS 2-3/8" 4.6 / L-80 7,190 (MD) 6,075 (TVD) Tubing (size, grade, measured and true vertical depth) SS 2-3/8" 3.02 & 4.6 / L-80 7,091 (MD) 5,995 (TVD) Packers and SSSV (type, measured and true vertical depth) D&L Oil Tool 308 (MD) TRSV 277 (MD) Hydroset II Pkr 308 (TVD) 277 (TVD) 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 72 40 0 547 76 Subsequent to operation: 56 145 71 81 82 14. Attachments (required Per 20 arc 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations Exploratory ❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑' Gas WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 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: 318-549 Authorized Name: Stan W. Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarlg a hilcom.com Authorized Signature: f26= L-. Date:Z Z Zn 11 Contact Phone: (907) 283-1329 �9 L Form 10-404 Revised 412017 `l//_ / !/ ;-3, Ie� RBDMSLRv APR 2 2 7019 Submit Original Only Trading Bay Unit Well: SCHEMATIC astComp leted: 03/27/19 HilcorD Alaska. LLC PTD: 197-130 API: 50-733-10057-03 RKB =39.30' CASING DETAII PBTD = 8,417' TO = 8,525' SIZE WT I GRADE CONN ID TOP BOTTOM 20" Driven Conductor Welded )rypl ID Surface 277' 16" 75 J-55 8rnd ST&C 15.124 Surface 413' 13-3/8" 61 J-55 BTC 12.515 Surface 1,871' 9-5/8" 47 N-80 BTC 8.681 Surface 3,500'(KOP) 7„ 29 P-110 BTC TKC 6.184 surface 2,507' ' 2,078' iW 29 L-80 BTC TKC 6.184 2,507' 8,510' ' 3,484' 1.901" 4.250" 4,049' 3,484' 1.901" 4.250" GLM k2-2-3/8"MANA SPMO-1.0Fstring mandrel) Tubing Detail 5,119' 4,3]9' 1.901" 4.250" GLM N3-2-3/8"MANA SPMO-1.0E-LT(side string mandrel) Long String 5,844' 4,973' 1.901" 4.250" GLM e4-2-3/8"MANA SPMO-1.0E-LT(side string mandrel) ' 5490' 1.901" 4.250' 6,976' 5,490' 1.901" 4.250" GLM p5-2-3/8"MANA SPMO-I.OF-LT (side string mandml) ' 5,981' 1.901" 4.250" 2-3/8" 4.6 L-80 IBT SCC 1.995 Surf 7,190' Short String - Long Side XN, Short Side RN w/ plug Installed on short string side 6,0)5' 3.343" 3.250" E 7,091' 5,995 1.995"1 2-3/8" 4.6 L-80 IBT SCC 1.995 Surf 244' 2-3/8" 3.02 L-80 8T5-8 1.278 244' 307' 2-3/8" 4.6 L-80 IBTSCC 1.995 307' 7,091' 16" Casing cut off below wellhead when set 12/24/1966 Perforation Details zone Top MO) Bottom (MD Top IPVD) Ia..elry DeYll Amount5pF reupth Uepta 10 [ID No Not M01 )rypl ID ODItem 2,194' 2,283' 110' shed, String Open B 2,723' 27Y 1.875" 3.750" 2 526' 12Y 5 07/24/13 Weatherford TRSV 308' 2.390" 5.950" A 308' 308' 1.501' 5.950" Packer-D&L Oil Tools Hydmset II 2-7/8"x1.900 w/ Weatherford vent valve 357 1.875" 2.375" B 358' 358' 1.710" 2.375" Nipples- Long Side X, Short Side ' 2,078' iW 1.901" 4.250" c 2,290' 2,078' 1.903' 4.250" GLM k1-2-3/8"MANA SPMO-1.0F1T(side string mandrel) ' 3,484' 1.901" 4.250" 4,049' 3,484' 1.901" 4.250" GLM k2-2-3/8"MANA SPMO-1.0Fstring mandrel) ' 4,379' 1.90V 4.250" 5,119' 4,3]9' 1.901" 4.250" GLM N3-2-3/8"MANA SPMO-1.0E-LT(side string mandrel) ' 4,9]3' 1.901" 4.250" 5,844' 4,973' 1.901" 4.250" GLM e4-2-3/8"MANA SPMO-1.0E-LT(side string mandrel) ' 5490' 1.901" 4.250' 6,976' 5,490' 1.901" 4.250" GLM p5-2-3/8"MANA SPMO-I.OF-LT (side string mandml) ' 5,981' 1.901" 4.250" 7,075' 5,981' 1.90Y 4.250" GLM 46-2-3/8"MANA SPMO-1.0E-LT(side string mandrel) ' 6,074' 1.791" 2.375" D 7,090' 5,994' 1.56" 2.375" "Nipples - Long Side XN, Short Side RN w/ plug Installed on short string side 6,0)5' 3.343" 3.250" E 7,091' 5,995 1.995"1 2.375" WLEGS Oil Tools 2-3/8" Telescoping Unions w/24"stroke usedtomake upshcPtndn ewel ID1.750') Perforation Details zone Top MO) Bottom (MD Top IPVD) Bottom Amount5pF Date Comments B 2,438' 2,543' 2,194' 2,283' 110' S 07/24/13 Open B 2,723' 2,849' 2,424' 2 526' 12Y 5 07/24/13 Open B 3,570' 3,735' 3,101' 3,230' 165' 6 07/24/13 Open 8 3,784' 3,860' 3,268' 3,329' 76' 6 07/24/13 Open B 3,978' 4,026' 3,425' 3,465' 48' 6 07/24/13 Open B 4,102' 4,200' 3,528' 3,608' 98' 6 07/24/13 Open B 4,605' 4,720' 3,946' 4,043' 115' 6 07/24/13 Open C 4,730' 4,836 4,052' 4,124' 86' 6 07/24/13 Open C 4,838' 5,262' 4,143' 4,498' 424' 6 07/24/13 Open c 5,409' 5,444' 4,616' 4,649' 40' 6 07/24/13 Open c 5,470' 5,618' 4,670' 4,791' 148' 6 07/24/13 Open C 5,555' 5,620' 4,739' 4,]92' 6 6 8/15/1997 2-1/8' 0 degree Phased Strip Guns C 5,760' 5,875' 4,905' 4,997' 115' 6 07/24/13 Open C 5,795' 5,960' 4,934' S 065' 165' 6 1 8/15/1997 2-1/8"0 degree Phased Strip Guns C 5,8W, 5,955' 5,0119' 5,093' 65' 6 1 07/24/13 Open c 6040' 6,167' 5,129' 5,234' 127' 6 1 07/24/13 Open C 6,050' 6,168' 5,13]' 5,235' 118' 6 8/15/1997 2-1/8" O degree Phased Strip Guns C 6,203' 6,275' 5,264' 5,324 7V 6 8/15/199] 2-1/8" 0 degree Phased Strip Guns c 6,225' 6,400' 5,282' 5,427' 175' 6 07/24/13 Open c 6,382' 6,402' 5,412' 5,429' 20' 6 8/15/1997 2-1/8"0 degree Phased Strip Guns c 6,519' 6,546' 5,526' 5,549' D' fi 07/24/13 Open D 6,962' 7,022' 1 5,889' 5,938' 60' 6 07/24/13 Open D 7,052' 7,078' 1 5,963' 5,984' 26 6 07/24/13 Open 0 7,160' 7,190' 1 6,051' 6,075' 30' 6 07/24/13 Open D 7,350' ],489' 6,20]' 6,323' 139' 6 07/24/13 Open D 7,610' ],fi]0' 6,427' 6,478' or 6 07/24/13 Open D 7,690' 7,]56' 6,495' 6,552' 11 6 5/12/1997 2-1/8" 0 degree Phased Strip Guns D 7,698' ],850' 6,502' 6,634' 152' 6 07/24/13 Open E 7,884'],917' 6,663' 6,692' 33' 6 5/12/1997 2- 8" 0 degree Phased Stnp Guns E E 8,022' 8,042' 8,055' 8,0]5' ]82' 6,]99' 6,86,810' 27' 33' 33' 6 6 07/24/13 5/1]/199] Open 2-1/8'0 degree Phased Strip Guns E 8,192' 8.260' 6,928' 6,896' 68' 6 07/24/13 Open E 8,266' 8,310' 6,991' ],029' 44' 6 07/24/13 Open E 8,318' 8,386 1 7,036' 7,094' 68' fi 07/24/13 Open Revised By: JILL 04/22/2019 Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Trading Bay St A-03RD3 Rig 56 50-733-10057-03-00 1 197-130 3/17/19 1 3/27/19 Daily Operations: 03/17/2019 -Sunday Prep & skid rig to well center A-03rd3, safe out same. R/U & circulate well to production had 0 on annulus, 80 psi on tubing. Pumped 2.5 BPM, ICP 1185 after catching fluid 7 bbls, got returns @ 36 bbls pumped. Pumped 390 bbls when returns changed from thick emulsion to an emulsion water mix. Cont. pumping total of 560 bbls had dirty emulsified water back, shut down monitor one hour, had vac on tubing & static on annular. Pump an additional 300 bbls FIW at 2 BPM/875 psi. Had full returns on annulus but never cleared up. Shut down. Tubing and annulus on slight vacuum. Remove circulating lines from tree. Set BPV. Had to acidize profile to get BPV set. Nipple down tree. Verify lift threads to be 3 1/2" TC -2. Install blanking plug. Set riser and DSA. Nipple up BOPE. Fluid Losses Total: Daily FIW: 210 bbls, Total FIW: 210 bbl, Sized Salt: Saturated Salt: 03/18/2019 - Monday Finish nippling up BOPE and function test same. Make up testjoints and get stack measurements. Flood stack and choke manifold for testing. Shell test stack while waiting on inspector. Repair leak at HCR flange. Grease choke manifold valves. Re - pressure test (good). Test BOP'S at 250 L/2500 H on 2 7/8". AOGCC (Adam Earl) on board to witness test. Pull 2 7/8" test joint and perform accumulator draw down test. Attempt to test blind rams. Door seal leaking on blind rams. Expedite door seals from Weatherford. OSK heliport on weather hold due to low ceilings/fog. While waiting on weather, pumped 98 bbls of 9.4 ppg FIW to TBPF at 2.5 BPM to vacate pit volume for FIW. Change out door seal on Weatherford double gate. Test blind rams at 250 L/2500 H. Install 3 1/2" testjoint. Test pipe rams at 250 L/2500 H. Fluid Losses Total: Daily FIW: 0 bbls, Total FIW: 0 bbls, Sized Salt: Saturated Salt: Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Dale End Date Trading Bay St A-03RD3 Rig 56 50-733-10057-03-00 1 197-130 1 3/17/19 1 3/27/19 Daily Operations: 03/19/2019-Tuesday Test BOPE repair leak on 3 1/2" test jt & reinstall, test good. R/D test eq. & build 3% KCL fluid in pits. R/U & pump down tubing, pump 2.5 BPM, 1420 psi, no returns or pressure build on annulus. P/U 2 7/8" landing jt & m/u same. Pull hanger @ 74k, cont t/90k packer pulled free. R/u with closed annular to take returns to production. Pump 75 bbls down tubing no returns, bleed 300 psi to production. Pump 20 bbls down annulus @ 650 psi, pump 58 bbls down tubing @ 2.5BPM, 1420 psi, no returns. R/U & pump down annulus, pressure build to 900 psi unable to circ. bleed pressure off, pump down tubing with no returns. Swap to annulus pumped 5bbls & pressured up, bled off pressure, make multiple attempts alternating between pumping down tubing and backside w/o success. Bleed off pressure and attempt to move string (able to pick up but unable to slack off). Wait on Pollard E-line crew. Break off circulating line and head pin. Preparing to rig up a-line. R/U wireline lubricator, sheaves and circulating line to perf tubing below packer at 413'. RIH with Pollard a-line to 250' (could not go past). Pulled up to 206' (pulled tight, unable to pull more out of fear of shearing loose of tool). Make several unsuccessful attempts to work tools up hole. Rig up and pump 2 bbl. diesel down tubing with test pump. Work e-line up to 150' and RIH to 450'. tie in and shoot 8 holes in 6' pupjt. below packer from 428' to 429.5'. Saw 85 psi increase in tubing pressure. Rig up and bleed pressure off tubing to 0 psi through choke manifold. (Did not see any fluids back during bleed off). Close TIW valve. R/D lubricator and e- line. R/U and circulate down tubing (fluid packed at 13 bbl away) 25 spm with 300 psi. with no returns. (30 bbl total pumped down tbg.) R/U and attempt to reverse circulate with no success. Monitor well and R/U to pull ESP. Fluid Losses Total: Daily FIW: 0 bbls, Total FIW: 0 bbls, Sized Salt: Saturated Salt: 03/20/2019- Wednesday Cont. prep to pull OOH, had hyd issue troubleshoot & repair. Fill tubing, pull hanger to floor & I/d same. Cont. pulling F/5339' t/4950' and tie into spoolers to packer, filling tubing as necessary. R/U & circulate hole volume to production at 3.5 BPM, 1000 psi. Cont. POOH L/D 2 7/8" completion (/4950' to 1308'. Fluid losses to hole averaged 28.6 bbl/hr. Cont. POOH L/D 2 7/8" completion (/1308' to ESP. Cable and Tubing f/ 4199' down in rough shape with pitting on collars and tubes. Recovered 274 tubing Canon clamps and 9 bands. Fluid losses to hole 35 bbl/hr. R/U and L/D ESP pump and motor assembly. Recovered 19 motor clamps and 1 splice clamp. Fluid losses to hole 35 bbl/hr. Fluid Losses Total: Daily FIW: 435 bbls, Total FIW: 645 bbls, Sized Salt: Saturated Salt: 03/21/2019-Thursday Clean & clear floor, clean drill deck. R/U W/I RIH w/ 6.05" junk basket t/ 3815' WLM, tagged up. POOH RIH w/ 5.88" GR tagged @ 8044' WLM. POOH RIH w/ 13/4" Bailer tag @ 8044', work down t/8046' WLM. POOH recover sand in bailer. POOH r/d W/L. Decision made to make cleanout run. P/U Kelly. Test stand pipe manifold and Kelly valves with 250 psi /2500 psi for 5 min each. (Good tests). Offload 2-3/8" tbg, 3-1/2" DP and 4-3/4" DC from boat. Make up clean out BHA (6" bit - B/S - 6 ea. 4-3/4" DC). RIH with cleanout BHA on 3-1/2" DP out of derrick to 6272'. (Complete offloading 2-3/8" tbg from boat while TIH.) M/U head pin and break circulation w/ MP #1. R/U to RIH picking up DP out of V-door. Continue RIH picking up 3-1/2" DP out of V- door (Strap and drift in V-door) f/ 6272'to 8045'. Fluid Losses Total: Daily FIW: 771 bbls, Total FIW: 1416 bbls, Sized Salt: Saturated Salt: Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Trading Bay St A-03RD3 Rig 56 50-733-10057-03-00 1 197-130 3/17/19 1 3/27/19 Daily Operations: 03/22/2019 - Friday Cont. RIH with c/o assy t/ 8055', tag, up wt 140k, do wt 90k. P/U Kelly wash down t/ 8405' ream when necessary, 7BPM, 1650psi, reamed through tight spot @ 8327'- 8343'. CBU x3 till clean, 7 BPM, 1650 PSI, stand back Kelly. Short trip t/7447', up wt 145k, do wt 90k. RIH tag 1.5' fill. Stand back Kelly, pooh I/d 3 1/2" wk string to 4290'. Monitoring well and pipe displacement with continuous hole fill from active system. Continue POOH standing back 3 1/2" wk string f/4290' leaving 10 stands and BHA in hole. Monitoring well and pipe displacement with continuous hole fill from active system. M/U Storm packer, RIH 4 stands (PUW & SOW 35K), set packer @ 392', pressure test to 2500 psi (Good test). Release from packer and stand back DP. Drain stack and prep to remove BOPS for tbg spool swap. Pull master bushings. Clean out drip pan. Pull flow nipple. Pull bottom off drip pan. Remove flow nipple boot off annular, MU BOP picking beam on annular. Work on breaking bolts loose on tbg spool. (Bled 700psi of gas off 9 5/8" X 7" annulus through vent line to flare.). Fluid Losses Total: Daily FIW: 850 bbls, Total FIW: 2266 bbls, Sized Salt: Saturated Salt: 03/23/2019 -Saturday Nipple down and pull 13 5/8" riser, DSA and tubing spool to rig floor. Install new tubing spool with NOS rep. ipple up 13 5/8" riser, DSA and BOP's to new tubing head. (test void on tubing spool w/ 500 psi for 5 min and 3000 psi for 15 min (Good Test). M/U landing jt. and half of dual string hanger for dummy run, lower hanger and set in well head to check orientation. L/D hanger and landing jt. M/U dual test jts (2 3/8" & 2 7/8") to test plug, run and set test plug in wellhead. Test lower VBR pipe rams and all breaks from tubing swap w/ 250 psi /2500 psi for 5 min each. (Good Test). Unseat test plug, rotate 180` and reseat plug. Test other side of lower VBR pipe rams w/ 250 psi / 2500 psi for 5 min each. (Good Test). Rig down test equipment. Canrig tech attempt to calibrate Rig Watch rotary torque sensor against rig's, unable to get Canrig's to work. Did get Rotary RPM working. Pick up Tripoint Storm Packer Retrieval tool and RIH to 392'. Wash down to top of packer and release packer. (Took 19 bbl to get returns) POOH and L/D storm Packer. Continue out of hole stand back remaining 10 std. of 3 1/2" work string and L/D 6 ea. 4 3/4" DC. Fluid losses to hole 35 bbl/hr. R/U Weatherford equipment to run Dual Completion. RIH with Dual String Gas Lift Completion (2 3/8" 4.6# L-80 IBT tubing) to 1450'. Fluid Losses Total: Daily FIW: 165 bbls, Total FIW: 2431 bbls, (� Sized Salt: Saturated Salt: 03/24/2019 -Sunday Cont. RIH with Dual String Gas Lift Com pletion 2 3/8" 4.6# L-80 IBT tubing) f 1450' t/5500'. Fluid loss rate 35 BPH-. Cont. RIH with Dual String Gas Lift Completion (2 3/8" 4.6# L-80 IBT tubing) f/ 5500' t/6900'. M/U DLESP Hyd. Packer to string. When picking up out of slips packer sheared lower slip section. (PUW= 66K, SOW=45K). L/D packer and install safety valves on dual string. Fluid loss rate -35 BPH. Waiting on manufacture's recommendations/options for replacement or repair of packer. Monitor well, clean and organize rig, service equipment, mix 1-1/2% KCL to top off active system and reserve pits. Fluid Losses Total: Daily FIW: 840 bbls, Total FIW: 3271 bbls, Sized Salt: Saturated Salt: Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Trading Bay St A-03RD3 Rig 56 50-733-10057-03-00 197-130 3/17/19 1 3/27/19 Daily Operations: 03/25/2019 - Monday Send TriPoint packer in on boat to be rebuilt. Continue to monitor well. Clean and organize rig. Service equipment, re -position movingjacks and assist Pollard Wireline with R/U for slick line work in cellar on well A-31. Fluid losses to well @ 35 BPH. Continue waiting on packer. (During tear down and inspection it was determined that rebuilding original packer was not an option) Assisting wireline with R/U and as needed on A-31 in cellar. Work on MP #1 middle fluid end and change out swab. Continue cleaning and servicing rig equipment. Monitoring well with continuous hole fill from active system. Building fluid as needed. Fluid loss rate to hole 30 BPH. TriPoint having cross overs cut to assemble replacement packer (DLESP Packer 7" X 2- 7/8" X 1.90" ) Continue assisting wireline as needed on A-31 in cellar. M/U hanger halves to tubing singles with pups on top of hangers. Rig down Pollard wireline from A-31. Offload packer assembly from boat. Rig up and RIH with 2-3/8" completion f/6900'. M/U packer assembly, function test vent valve. M/U safety valve, hookup control lines and function test (Good). RIH to 6930'. Unable to go past 6930', free picking up. (Up Wt. 70k, Dn. Wt. 50k). Continue working pipe to get past 6930'. L/D Safety valve and single from short side. Pull up to top of packer and observe that X/O from 1.90 NU LORD to 2-3/8" IBT on short string side of packer had pulled loose from top of packer. L/D packer. Fluid Losses Total: Daily FIW: 780 bbls, Total FIW: 4051 bbls, Sized Salt: Saturated Salt: 03/26/2019 -Tuesday Finished laying do Pkr. Discussed options with town and decided to get some smaller pipe [1.66 tbg]. Line up pipe and XOs to be inspected and or re -cut. Work on housekeeping and rig projects while waiting on tools. Assist Pollard with rig up and slickline on A-31. [A-03 is taking 30 BPH]. Jim Regg with AOGCC waived required BOPE test due today. Waiting on tools. Work on rig projects. RU water feed line for cmt unit. Pull guards and pump out oil in #1 mud pump. Assist Pollard with slickline on A- 31. Fluid losses to hole @ 30 BPH until 20:00 hours when they decreased to 26 BPH. Rig down Pollard wireline. Make up X/O's and pups into top of packer assembly on deck. Pressure test connections to 1500 psi (no leaks) Fluid losses to hole @ 26 BPH. Pick up Packer assembly. Make up to short and long string. Function test vent valve Good . Make up safety valve assembly on long side and function test (Good). Make up 2 jt. 1-1/2" CS Hydril pipe and space out to long string. RIH with 2-3/8" 4.7# L-80 IBT tubing. M/U hangers and lower string to rig floor. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number start Date End Date Trading Bay St A-03RD3 Rig 56 50-733 10057-03-00 197-130 3/17/19 1 3/27/19 Daily Operations: 03/27/2019- Wednesday MU floor valve on long string and wait for extra 2 3/8 EUE X 2 7/8 EUE xo with a 2" ID. Prep to MU landing jt. XO arrived on platform at 07:18 hrs. MU xo's and landing jts. Run control lines through hanger. Land out hanger and verify hanger is down. RILDS. Clear floor of dual elevators and slips. Break out top pups on landing jts. Install floor valves and RU slickline with Pump in sub. RIH with standing valve on slickline. Had issues getting past SSSV and may have sheared tool. RIH to 7190' WLM. Fluid pack well. Pressure up do LS to 3900 psi and hold for 30 min to set pkr. Bled do to 3650 psi. Bleed off LS and pressure uo nn, ann to test PKR to 1650 Psi. Pressure bled down to 1575 psi in 30 min on a chart. Bled off press and RU on SS. Press up to 1650 psi and hold for 30 min on a chart. PCH with Pollard slickline and recovered standing valve. RD test lines while PCH. Finish RD Pollard and test equip. Break out, pull, and break down landingjt's. RD Weatherford tongs. Set BPVs in both strings. Clear floor of tools and prep for nipple dn. Pull riser and air boot off top of Annular. De-energize Accumulator, pull lay down mouse holes. Make up BOP lift beam to top of Annular and hook into with cellar bridge cranes. Unbolt BOPS from top of riser, pick up BOPS and trolley over to east side of cellar. Make up lifting plate to top of riser, unbolt DSA from top of tubing spool and pull riser with DSA to rig floor. Lower tree SSV and choke valves to well head room. Lower tree to well head, make several unsuccessful attempts to stab adapter spool over dual string hanger necks. Pull tree to rig floor and split at top of master valve. Lower adapter flange and master valve to well head and stab onto tubing spool. Make up to tubing spool and test void to 500 psi (5 min) and 5000 psi (15 min) - Good Test. Lower and make up upper section of tree to master valve. Test void at connection with 500 psi / 5000 psi - Good Test. Make up SSV and choke valve on tree. Pull BPVs and replace with TWCs. Test both sides of tree to 250 and 5000 psi. RD test equip and turn well over to production. Fluid Losses Total: Daily FIW: 248 bbls. Total FIW: 5063 bbls. Sized Salt: Saturated Salt: Regg, James B (DOA) From: Regg, James B (DOA) 31-,7 Sent: Tuesday, March 26, 2019 9:31 AM 4 1 To: 'Harold Soule - (C)' Subject: RE: A03rd3 Trading Bay State A-03RD3 PTD 1971300 Thank you for the email summary. As discussed by phone, AOGCC waives the required BOPE test due today. Jim Regg Supervisor, Inspections AOGCC 333 W.7'h Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907- 793-1236 or im.re¢e@alaska.eov. From: Harold Soule - (C) <hsoule@hilcorp.com> Sent: Tuesday, March 26, 2019 9:25 AM To: Regg, James B (DOA) <jim.regg@alaska.gov> Subject: A03rd3 Hello Mr Regg We are due to test BOPE today on A-03. We started RIH w/completion Sunday 241h about 12:30 in the morning anticipated landing out early morning yesterday. Sunday night we m/u packer, picked it up & it had sheared. We sent it in to get rebuilt but found compromised parts in it. They sent out a new packer with different configuration received 1:00 this morning, Went to run it & found there was an OD conflict, so we are having to have a new set of xo's built today to make it work. We have about 355' to run to land out after we get correct parts to do it. But with that said we may or may not get landed by midnight tonight. Harold Soule office 907-776-6675 Cell 907-227-9400 ywP�\ l//y.4',v THE STAT • Alaska Oil and Gas 0f/� T AS] /� Conservation Commission :== 1-1L J X1`1 _ 333 West Seventh Avenue 4.•.11111 >�' C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 LASY' Fax: 907.276.7542 www.aogcc.alaska.gov Stan Golis Operations Manager % Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Trading Bay Field, Middle Kenai B, C, D, and E Oil Pool, Trading Bay St A-03RD3 Permit to Drill Number: 197-130 Sundry Number: 318-159 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this 1‘ day of April, 2018. ECEIVED • • STATE OF ALASKA APR 10 2018 OtS ALASKA OIL AND GAS CONSERVATION COMMISSION 1/`X APPLICATION FOR SUNDRY APPROVALS GC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate 0 Repair Well 0 Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0 Change Approved Program El Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well 0 Alter Casing ❑ Other. ESP/GL Completion 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska, LLC ` Exploratory 0 Development 0' 197-130 " 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number Anchorage,AK 99503 50-733-10057-03-00 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A ' Will planned perforations require a spacing exception? Yes 0 No 0 1 Trading Bay St A-03RD3 • 9.Property Designation(Lease Number): 10.Field/Pool(s): E ADL0018731 Trading Bay Field/Middle Kenai B,C,D,Qil Pools / 3 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): ' 8,525 • 7,213 - 8,417 ' 7,121 653 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 277' 20" 277' 277' Surface 1,871' 13-3/8" 1,871' 1,740' 3,090 psi 1,540 psi Intermediate Production 3,500' 9-5/8" 3,500' 3,045' 6,870 psi 4,760 psi Liner 8,510' 7" 8,510' 7,200' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 2,438-8,386 ` 2,194-7,094 2-7/8" 6.5#/L-80 5,276 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): ESP Packer w/vent valve/Baker SSSV • 413'(MD)413'(TVD)&300'(MD)300'(TVD) 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development 0 ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 5/10/2018 OIL 0" WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stan W.Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarioweOhilcorp.com 13 tk.:‘ Date: b ' I Contact Phone: 283-1329 Authorized Signature: t b t g COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 31_y I5q Plug Integrity ❑ BOP Test ti Mechanical Integrity Test El Location Clearance 1:1111 Other: 41 ., Ci'.) %o.s, (3 U e /,J Post Initial Injection MIT Req'd? Yes 0 No ❑ J PR 13 201% Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: /O _/ 0 � RB�M APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 11 II. te_,, f1�'l NI lid it ORIGINAL y_,,-, Q � Submit Form and b(�� Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate Well Work Prognosis Hileorp Alaska,LLC. Well Name: Monopod A-03RD3 API Number: 50-733-10057-03-00 Current Status: Oil Producer Leg: N/A Estimated Start Date: May 10, 2018 Rig: Monopod Platform Rig#56 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 197-130 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Mike Quick (907) 777-8442 (0) (907) 317-2969 (M) Current Bottom Hole Pressure: 2,750 psi @ 6,913'TVD 0.398 psi/ft(7.65 ppg)ESP Gauge Maximum Expected BHP: 2,750 psi @ 6,913'TVD 0.398 psi/ft(7.65 ppg)ESP Gauge Maximum Potential Surface Pressure: 653 psi Using 0.1 psi/ft gradient per 20AAC 25.280(b)(4) Brief Well Summary: The A-03RD3 is currently completed in the B, C, D, & E sands.The purpose of this work over is to pull the failed pump and install a new ESP to improve drawdown with a backup option of gas-lift. / Last Casing Test: 07/18/2013 2,430' MD to 1,500 psig for 30 minutes on chart Procedure: 1. MIRU Monopod Platform Rig#56. 2. Circulate hydrocarbon off of well. 3. Workover fluid to be FIW with LCM as needed to balance well, BOP's will be closed as needed to circulate the well. 4. ND Wellhead, NU BOP and test to 250psi low/2,500psi high. (Note: Notify AOGCC 24 hours in advance of test to allow them to witness test). 5. Monitor well to ensure it is static. 6. POOH with completion. 7. Optional: RIH w/cleanout assembly. Circulate clean. POOH. 8. PU and RIH with new completion assembly consisting of the ESP, Gas Lift Mandrels, High-set Packer w/Vent Valve, &SSSV. 9. Set Packer at±300'. Pressure test to 1,500 psig and chart for 30 minutes. 10. ND BOP, NU wellhead and test. 11. Turn well over to production. 12. Conduct SVS testing per AOGCC regulations. Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic Current 4. Wellhead Schematic Proposed 5. BOP Drawing 6. Fluid Flow Diagrams 7. RWO Sundry Revision Change Form 410 Trading Bay Unit II • WelSCHEMATIC Last pD3 Completed: 02/08/2015 Hilcora Alaska.LLC PTD: 197-130 API: 50-733-10057-03 RKB=39.30' RKB to MSL=112';RKB to Seafloor=174' CASING DETAIL 1 SIZE WT GRADE ' CONN ID TOP BOTTOM 2 _ L.. 20" Surface 277' 20" 3 16" 75 J-55 8 rnd ST&C 15.124 Surface 413' 13 3/8" 61 J-55 BTC 12.515 Surface 1,871' 9-5/8" 47 N-80 BTC 8.681 Surface 3,500'(KOP) 16" ) 29 P-110 BTC TKC 6.184 Surface 2,507' 7 29 L-80 BTC TKC 6.184 2,507' 8,510' Squeeze Perfs .. Tubing Detail @ 1,050' 2-7/8" 6.5 L-80 8rd EUE 2.441" Surface 5,276' 4 Tubing Punch-12 each,0.25"holes from 5,250'to 5,253' 13-3/8" \ Tbg Up wt=42,000# Down Wt=32,000# 4 16"Casing cut off below wellhead when set 12/24/1966 JEWELRY DETAIL Item MD TVD ID OD Description 1 39.30' 39' 11.00 Tubing Hanger FMC-TC-EC 5 2 300' 300' 2.313 4.400 SSSV-Baker Tubing Retrievable 6 3 413' 413' 2.441 5.930 ESP Packer w/Vent Valve 4 1,758' 1,649' 2.441 4.625 GLM 5 2,280' 2,070' 2.441 4.625 GLM 9-5/8` 6 2,331' 2,110' 2.313 2.875 X Nipple B 7 5,276' 4,510' - 4.000 Discharge,Bolt-On 8 5,279' 4,512' - 4.000 Pump(x2)125 Stage SF1750&76 Stage SFGH2500 9 5,322' 4,548' - 4.000 Intake 10 5,344' 4,566' - 4.000 Motor 456 Series,FMP1(180HP/2610V/47A) 11 5,381' 4,597' 4.560 Gauge(GRC3500)/Centralizer/Anode 7 ' Perforation Details 8 - Zone Top Bottom Top Bottom Amount SPF Date Comments1Comments (MD) (MD) (TVD) (TVD) jwr 9 = C B 2,438' 2,548' 2,194' 2,283' 110' 5 07/24/13 Open _ - B 2,723' 2,849' 2,424' 2,526' 125' 5 07/24/13 Open Mit_ 0 = B 3,570' 3,735' 3,100' 3,230' 165' 6 07/24/13 Open - B 3,784' 3,860' 3,268' 3,329' 76' 6 07/24/13 Open B 3,978' 4,026' 3,425' 3,465' 48' 6 07/24/13 Open - 11 __ B 4,102' 4,200' 3,528' 3,608' 98' 6 07/24/13 Open B 4,605' 4,720' 3,946' 4,043' 115' 6 07/24/13 Open = C 4,730' 4,816' 4,052' 4,124' 86' 6 07/24/13 Open C 4,838' 5,262' 4,143' 4,498' 424' 6 07/24/13 Open C 5,404' 5,444' 4,616' 4,649' 40' 6 07/24/13 Open C 5,470' 5,618' 4,670' 4,791' 148' 6 07/24/13 Open C 5,555' 5,620' 4,739' 4,792' 65' 6 8/15/1997 2-1/8"0 degree Phased Strip Guns C 5,760' 5,875' 4,905' 4,997' 115' 6 07/24/13 Open C 5,795' 5,960' 4,934' 5,065' 165' 6 8/15/1997 2-1/8"0 degree Phased Strip Guns ----=-- D C 5,890' 5,955' 5,009' 5,093' 65' 6 07/24/13 Open C 6040' 6,167' 5,129' 5,234' 127' 6 07/24/13 Open C 6,050' 6,168' 5,137' 5,235' 118' 6 8/15/1997 2-1/8"0 degree Phased Strip Guns C 6,203' 6,275' 5,264' 5,324' 72' 6 8/15/1997 2-1/8"0 degree Phased Strip Guns = C 6,225' 6,400' 5,282' 5,427' 175' 6 07/24/13 Open C 6,382' 6,402' 5,412' 5,429' 20' 6 8/15/1997 2-1/8"0 degree Phased Strip Guns C 6,519' 6,546' 5,526' 5,549' 27' 6 07/24/13 Open D 6,962' 7,022' 5,889' 5,938' 60' 6 07/24/13 Open D 7,052' 7,078' 5,963' 5,984' 26' 6 07/24/13 Open D 7,160' 7,190' 6,051' 6,075' 30' 6 07/24/13 Open D 7,350' 7,489' 6,207' 6,323' 139' 6 07/24/13 Open E D 7,610' 7,670' 6,427' 6,478' 60' 6 07/24/13 Open _ D 7,690' 7,756' 6,495' 6,552' 66' 6 5/12/1997 2-1/8"0 degree Phased Strip Guns D 7,698' 7,850' 6,502' 6,634' 152' 6 07/24/13 Open E 7,884' 7,917' 6,663' 6,692' 33' 6 5/12/1997 2-1/8"0 degree Phased Strip Guns - E 8,022' 8,055' 6,782' 6,810' 33' 6 07/24/13 Open Top of Fill = E 8,042' 8,075' 6,799' 6,827' 33' 6 5/12/1997 2-1/8"0 degree Phased Strip Guns 8,411' E 8,192' 8,260' 6,928' 6,896' 68' 6 07/24/13 Open - nic �'1'+ "^ E 8,266' 8,310' 6,991' 7,029' 44' 6 07/24/13 Open Max Hole Angle=40° E 8,318' 8,386' 7,036' 7,094' 68' 6 07/24/13 Open PBTD=8,417' TD=8,525' Revised By:JLL 05/08/15 Trading Bay Unit Well:A-3RD3 II 0 PROPOSED • Last Completed: FUTURE Hilcora Alaska,LLC PTD: 197-130 API: 50-733-10057-03 RKB=39.30' RKB to MSL=112';RKB to Seafloor=174' CASING DETAIL I 1 SIZE WT GRADE CONN ID TOP BOTTOM 2 20" Surface 277' 20:4i r 3 16" 75 J-55 8 rnd ST&C 15.124 Surface 413' 13-3/8" 61 J-55 BTC 12.515 Surface 1,871' 9-5/8" 47 N-80 BTC 8.681 Surface 3,500'(KOP) 16" 7„ 29 P-110 BTC TKC 6.184 Surface 2,507' I. 29 L-80 BTC TKC 6.184 2,507' 8,510' Squeeze Ports .' Tubing Detail @ 1,050' 2-7/8" 6.5 L-80 8rd EUE 2.441" Surface ±5,275' 1 4 16"Casing cut off below wellhead when set 12/24/1966 13-3/8" ¢_ 1 , A s JEWELRY DETAIL Item MD TVD ID OD Description 1 39.30' 39' Tubing Hanger FMC-TC-EC , 2 ±300' ±300' - SSSV 3 ±415' ±415' 2.441 ESP Packer w/Vent Valve 4 ±1,760' ±1,650' 2.441 GLM l:5 5 ±2,280' ±2,070' 2.441 GLM 6 ±5,245' ±4,484' 2.313 X Nipple I ±5,275 ±4,509' - Discharge,Bolt-On 9-5/8" _ - Pump Intake A ' i 7 Seals B Motor ±5,400' ±4,612' - Anode Perforation Details '-z-'-' Top Bottom Top Bottom Zone (MD) (MD) (TVD) (TVD) Amount SPF Date Comments C B 2,438' 2,548' 2,194' 2,283' 110' 5 07/24/13 Open - - Z=- B 2,723' 2,849' 2,424' 2,526' 125' 5 07/24/13 Open - - B 3,570' 3,735' 3,100' 3,230' 165' 6 07/24/13 Open if 7 _ B 3,784' 3,860' 3,268' 3,329' 76' 6 07/24/13 Open . =",-=- B 3,978' 4,026' 3,425' 3,465' 48' 6 07/24/13 Open B 4,102' 4,200' 3,528' 3,608' 98' 6 07/24/13 Open B 4,605' 4,720' 3,946' 4,043' 115' 6 07/24/13 Open C 4,730' 4,816' 4,052' 4,124' 86' 6 07/24/13 Open C 4,838' 5,262' 4,143' 4,498' 424' 6 07/24/13 Open C 5,404' 5,444' 4,616' 4,649' 40' 6 07/24/13 Open = C 5,470' 5,618' 4,670' 4,791' 148' 6 07/24/13 Open E--- C 5,555' 5,620' 4,739' 4,792' 65' 6 8/15/1997 2-1/8"0 degree Phased Strip Guns C 5,760' 5,875' 4,905' 4,997' 115' 6 07/24/13 Open C 5,795' 5,960' 4,934' 5,065' 165' 6 8/15/1997 2-1/8"0 degree Phased Strip Guns 0 C 5,890' 5,955' 5,009' 5,093' 65' 6 07/24/13 Open C 6040' 6,167' 5,129' 5,234' 127' 6 07/24/13 Open C 6,050' 6,168' 5,137' 5,235' 118' 6 8/15/1997 2-1/8"0 degree Phased Strip Guns C 6,203' 6,275' 5,264' 5,324' 72' 6 8/15/1997 2-1/8"0 degree Phased Strip Guns = C 6,225' 6,400' 5,282' 5,427' 175' 6 07/24/13 Open C 6,382' 6,402' 5,412' 5,429' 20' 6 8/15/1997 2-1/8"0 degree Phased Strip Guns C 6,519' 6,546' 5,526' 5,549' 27' 6 07/24/13 Open D 6,962' 7,022' 5,889' 5,938' 60' 6 07/24/13 Open D 7,052' 7,078' 5,963' 5,984' 26' 6 07/24/13 Open = D 7,160' 7,190' 6,051' 6,075' 30' 6 07/24/13 Open - D 7,350' 7,489' 6,207' 6,323' 139' 6 07/24/13 Open E D 7,610' 7,670' 6,427' 6,478' 60' 6 07/24/13 Open D 7,690' 7,756' 6,495' 6,552' 66' 6 5/12/1997 2-1/8"0 degree Phased Strip Guns D 7,698' 7,850' 6,502' 6,634' 152' 6 07/24/13 Open E 7,884' 7,917' 6,663' 6,692' 33' 6 5/12/1997 2-1/8"0 degree Phased Strip Guns E 8,022' 8,055' 6,782' 6,810' 33' 6 07/24/13 Open Top of Fill = E 8,042' 8,075' 6,799' 6,827' 33' 6 5/12/1997 2-1/8"0 degree Phased Strip Guns 8.411' - E 8,192' 8,260' 6,928' 6,896' 68' 6 07/24/13 Open E 8,266' 8,310' 6,991' 7,029' 44' 6 07/24/13 Open Max Hole Angle=40° E 8,318' 8,386' 7,036' 7,094' 68' 6 07/24/13 Open PBTD=8,417' TD=8,525' Revised By:JLL 04/04/18 •11 • Monopod Platform A-3RD3 Current 04/05/2018 Ilelriirp tla',ka.1.1.t. Monopod Tubing hanger,FMC-TC- A-3RD3 B-EC,11 X 3'A TC-2 lift 133/8X95/8X7X27/8 and susp,w/3"type H BPV profile,300-1 pocket,4-'''A"continuous control line BHTA,Bowen,3 1/8 5M X 2.5 Bowen quick union I Ir Valve,Swab,WKM-M, . pouf 31/85M FE,HWO,DD trim o Valve,Wing,WKM-M, o d o; 3 1/8 5M FE,w/15" OMNI operator,DD trim Ilif ------/010: liksiala e.e 4 Valve,Master,WKM-M, 3 1/8 5M FE,HWO,DD trim IV Ise :: ... III .M. ._ I:: 1e 1 Tubing head,CW, I,1 't_IU Valve,WKM-M,21/16 5M 13 5/8 3M x 115M,w/2- — 1/1 FE,HWO,AA 2 1/16 SM SSO,w/HPS .. . _ i. ?' bottom,w/1-21/165M II __-'4 �� 1[0�0�o,I _i•-'. WKM-M valve I Qra Li 1III '1 III ;+ I�I Valve,CIW-FC,2 1/16 5M FE, Casing spool,McEvoy-SL, HWO,AA 135/83MX135/83M, �' ` n w/2-2 1/16 5M SSO 1jIlprifl :- 1.1 U� 1111 liNI=E; Casing head,Shaffer-KD, 1i:'' 13 5/8 3M X 13"SOWin bottom,w/2"LPO Iii — I IE Ip.liIi-;El 2"LP plug valve • Mood Platform 2018 BOP Stack Hilrn�p;Alawka,i.1A, ,lib Bottom of air boot flange Rig Floor 171 ,. FU 5'below rig floor 16' Pipe III III III III lit 4.54' • Hydril 1111 GK 13 5/8-5000 III III ill III II! 111 ill III in III 26.25' 0. 6 t Maim 27/8 x 5 variable rams /__-I� uIII. a 67' !k' 'a� 135/85M :� ��_Bf�ed Ili Ill !if III kit 21/165M manual and - .:1/165M manual and 2.26' HCR vavos for choke side "..R alves for kill side 1-1•urin• - - r Maims mita' LULU Itti Drill deck V Rise 13 5/8 5M FE X 135/85M FE 14.20' 111 lil Ili111 lii I!I flI III lit l!I 1.41' Ill Ill fil Ill 11.1 11 • • Monopod Rig#56 BOP Test Procedure Hileorp Alaska,LLC Attachment#1 Attachment #1 Hilcorp Alaska LLC. BOP Test Procedure: Monopod Rig # 56 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) Circulate down tubing taking returns to production off of the annulus and sweep gas and oil to production until returns are clean. 4) Confirm that well is static shooting fluid levels if necessary right before ND/NU. 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 per standard Monopod Rig#56 BOPE test procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, establish static fluid level, shoot fluid level with an echometer gun or tag with slick line to establish static fluid level if necessary. 2) Once the fluid level is established to be static, notify Hilcorp Anchorage Operations Engineer. 3) 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) Plug penetrations in hanger. For ESP wells- Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 4) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC-guy.schwartz@alaska.gov) and Mr. Jim Regg (AOGCC-jim.regg@alaska.gov )via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE • • Monopod Rig#56 BOP Test Procedure Hileorp Alaska,1.1.0 #1 b) With stack out of the test path, test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile /penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 5) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 6) 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. Note: BOPE high test pressures will be determined upon Approved Sundry.Test joint sizes will be determined upon well work. 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 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-2 (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 • Monopod Rig#56 BOP Test Procedure Hileorp Alaska,LLC Attachment#1 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-2. 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. 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-3. 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 C-1, C-2, and C-4 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 2nd set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre-charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. 8) Once 200 psi pressure build is reached,turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/-3,000 psi). Note: Make sure the electric pump is turned to "Auto", not "Manual" so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves,for correct operating position • Monopod Rig#56 BOP Test Procedure i,r�,aia,ka.LLCAttachment#1 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. 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STATE OF ALASKA AL __,CA OIL AND GAS CONSERVATION COMM.—TION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Repair Well❑ Plug Perforations Cl Perforate ❑ Other El Install ESP Performed: Alter Casing❑ Pull Tubing CI Stimulate-Frac ❑ Waiver El 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 El 197-130 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic El Service El 6.API Number: Anchorage, AK 99503 50-733-10057-03 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018731 Trading Bay ST A-03RD3 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s). Trading Bay Field/Middle Kenai C Oil,Middle Kenai D Oil,Middle Kenai B Oil Pools 11.Present Well Condition Summary: RECEIVED Total Depth measured 8,525 feet Plugs measured N/A feet MAR o 6 2015 true vertical 7,213 feet Junk measured N/A feet (� Effective Depth measured 8,417 feet Packer measured 413 feet AQGCC true vertical 7,121 feet true vertical 413 feet Casing Length Size MD ND Burst Collapse Structural Conductor 277' 20" 277' 227' Surface 1,870' 13-3/8" 1,870' 1,739' 3,090 psi 1,540 psi Intermediate Production 3,500' 9-5/8" 3,500' 3,045' 6,870 psi 4,760 psi Liner 8,510' 7" 8,510' 7,200' 8,160 psi 7,020 psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80 5,276'(MD) 4,510'(ND) 413'(MD) 300'(MD) Packers and SSSV(type,measured and true vertical depth) ESP Pkr 413'(TVD) Baker SSSV 300'(ND) 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 162 56 0 644 100 Subsequent to operation: 125 176 34 560 180 14.Attachments: '15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development[] Service ❑ Stratigraphic El Daily Report of Well Operations X 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ El SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 314-681 Contact Trudi Hallett Email thallett( hilcorp.com Printed Name Trudi Hallett Title Operations Engineer .alSignature Phone (907)777-8323 Date 3/5/2015 _ RBDM3� MAR - 6 2015 Form 10-404 Revised 10/2012 3-h-� Submit Original Only .k 3/7/` •ll Trading Bay Unit SCHEMATIC Well: A-3RD3 uacorp Alaska,LLC Completed: 02/08/2015 KB=101'RKB from MSL CASING AND PLUG DETAIL SIZE WT GRADE CONN ID TOP BOTTOM 1 I.) 20" 0 277' 2 � 3 . Jk J-5, 15.124 0 44 zo° , �cl III.) 13-3/8" 61 J-55 12.515 0 1870' IV.) 9-5/8" 47 N-80 8.681 0 3500'(KOP) • V.) 7" 29 L-80 6.184 0 8510' 1 Tubing 2-7/8" 6.5 L-80 8rd EUE 0 5,276' Tbg Up wt=42,0008 Down Wt=32,0008 B 4 TUBING DETAIL 13-3/8"Al , Item MD Min ID Description 1 39.30' Tubing Hanger FMC-TC-EC 2 300' - SSSV-Baker Tubing Retrievable 3 413' 2.441 ESP Packer w/Vent Valve 4 1,758' 2.441 GLM 5 2,280' 2.441 GLM 6 2,331' 2.313 X Nipple D 5 7 5,276' - Discharge,Bolt-On 8 5,279' - Pump(x2)125 Stage&76 Stage _ "+4Nw 6 9 5,322' - Intake 0-5/8" 10 5,344' - Motor 456 Series,FMP1 11 5,381' - Anode I - B Field inspection does not find 16"casing 11/2003 JJD 7 T Perforation Details H _ Top Bottom (MD) Bott (ND) (TVD)Top Bottom 8 = Zone Amount SPF Date Comments - B 2,438' 2,548' 2,194' 2,283' 110' 5 07/24/13 Open e0B9 E- ___ c B 2,723' - 2,849' 2,424' 2,526' 125' 5 07/24/13 Open B 3,570' 3,735' 3,100' 3,230' 165' 6 07/24/13 Open .(O = 3,784' 3,860' 3,268' 3,329' 76' 6 07/24/13 Open B 3,978' 4,026' 3,425' 3,465' 48' 6 07/24/13 Open B 4,102' 4,200' 3,528' 3,608' 98' 6 07/24/13 Open 11 B 4,605' 4,720' 3,946' 4,043' 115' 6 07/24/13 Open - C 4,730' 4,816' 4,052' 4,124' 86' 6 07/24/13 Open C 4,838' 5,262' 4,143' 4,498' 424' 6 07/24/13 Open C 5,404' 5,444' 4,616' 4,649' 40' 6 07/24/13 Open C 5,470' _ 5,618' 4,670' 4,791' 148' 6 07/24/13 Open C 5,555' 5,620' 4,739' 4,792' 65' 6 8/15/1997 2-1/8"0 degree Phased Strip Guns C 5,760' _ 5,875' 4,905' 4,997' 115' 6 07/24/13 Open = C 5,795' 5,960' 4,934' 5,065' 165' 6 8/15/1997 2-1/8"0 degree Phased Strip Guns C 5,890' _ 5,955' 5,009' 5,093' 65' 6 07/24/13 Open = p C 6040' 6,167' 5,129' 5,234' 127' 6 07/24/13 Open = C 6,050' 6,168' 5,137' 5,235' 118' 6 8/15/1997 2-1/8"0 degree Phased Strip Guns C 6,203' 6,275' 5,264' 5,324' 72' 6 8/15/1997 2-1/8"0 degree Phased Strip Guns C 6,225' 6,400' 5,282' 5,427' _ 175' 6 07/24/13 Open = C 6,382' _ 6,402' 5,412' 5,429' 20' 6 8/15/1997 2-1/8"0 degree Phased Strip Guns C 6,519' 6,546' 5,526' 5,549' 27' 6 07/24/13 Open D 6,962' 7,022' 5,889' 5,938' 60' 6 07/24/13 Open D 7,052' 7,078' 5,963' 5,984' 26' 6 07/24/13 Open D 7,160' 7,190' 6,051' 6,075' 30' 6 07/24/13 Open D 7,350' 7,489' 6,207' 6,323' 139' 6 07/24/13 Open D 7,610' 7,670' 6,427' 6,478' 60' 6 07/24/13 Open D 7,690' _ 7,756' 6,495' 6,552' 66' 6 5/12/1997 2-1/8"0 degree Phased Strip Guns E D 7,698' 7,850' 6,502' 6,634' 152' 6 07/24/13 Open - E 7,884' 7,917' 6,663' 6,692' 33' 6 5/12/1997 2-1/8"0 degree Phased Strip Guns _ E 8,022' _ 8,055' 6,782' 6,810' 33' 6 07/24/13 Open = E 8,042' _ 8,075' 6,799' 6,827' 33' 6 5/12/1997 2-1/8"0 degree Phased Strip Guns Top of Fill = E 8,192' 8,260' 6,928' 6,896' 68' 6 07/24/13 Open 8,411' E 8,266' 8,310' 6,991' 7,029' 44' 6 07/24/13 Open E 8,318' 8,386' 7,036' 7,094' 68' 6 07/24/13 Open Max Hole Angle=40° PBTD=8,417' TD=8,525' Revised By:JLL 03/05/15 Hilcorp Alaska, LLC Hiu.orp Alaska,LL.(: Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-03RD3 50-733-10057-03 197-130 2/3/2015 2/9/2015 Daily Operations: 02/03/15-Tuesday N/D and remove tree from Well Head Room. Inspect TBG HGR lift threads. Blank off chemical control line.Open SSSV and trap 4500 psi on control line with swedgelock check valve. MU 3 1/2" IBT Pin X Left Hand Acme PIN blanking plug to Tbg Hgr. MU 4" HT 38 test joint with 2 7/8" EUE box,ACME Box Test Sub.Space out test jt from top of blanking sub to rig floor. Mark RKB on test jt. (38.40'tag,38.65'MU with 5 turns to left.). Back out and lay down test joint. Daily fluid loss=776 bbls 3%8.6 KCL.Total Fluid Loss to Well=1036 bbls 3%8.6 KCL. Sized Salt Pill=40 bbls.Total Sized salt=40 bbls.Annulus Pressures:20"=0, 13 3/8"=80, 9 5/8" =50, 7"=0(Vac). Land and N/U Drilling Riser and BOPE and associated equipment. Clean up and organize work areas after N/U. Set Mouse Hole. 24 hr notice of upcoming BOPE Test sent to AOGCC on Monday, February 02,2015 3:09 PM. Rig up BOPE test equipment. Fill stack and warm up new annular preventer. 02/04/15-Wednesday Finish R/up test equipment and house clean work areas.Warm annular. Test BOPE on 4"and 2-7/8"test jts t/250 low and 2500 psi high as per AOGCC regulations.Test gas alarms.Build 40 bbl sized salt pill. Lay down test Joint,drain and blow down choke and test pump hoses.Strap weld 2 7/8' EUE X Acme xo to 2 7/8"test joint and retrieve ACME Blanking Sub from top of tubing hanger. Lay down same. Build 4"drill pipe landing joint crossed over to 3 1/2" IBT.Close blind rams and pump 15 bbls through BPV @ 1.5 BPM to put well on vac.Come down on pump.Well on vac through BPV. Pull BPV. Rig Inspection by Lou Grimaldi with AOGCC. Daily fluid loss=258 bbls 3%8.6 KCL. Total Fluid Loss to Well=602 bbls 3%8.6 KCL.Sized Salt Pill=40 bbls.Total Sized salt=80 bbls.Annulus Pressures:20'=0, 13 3/8"=122 psi, 9 5/8"'=160 psi. Lou Grimaldi with AOGCC arrived after BOPE test was complete. Discussed Test and operations and he performed rig inspection. MU 4"drill pipe landing joint to hanger. MU Top Drive.Sweep well to production pumping 180 bbls 8.6,3%KCL.loss rate @ 118 BPH.Shut in annulus and bull head 40 bbls sized salt pill and chase to EOP with 15 bbls KCL @ 3 BPM. Pressure steadily increasing and had to slow rate down to 1.5 BPM @ 8 bbls of chase pumped to keep from exceeding 350 psi. Down on pump, monitor loss rate with charge pump.Loss rate @ 95 bph diminishing to 30 bph in 90 minutes.Start mixing size salt pill while monitoring losses. Loss rate @ 25 BPH. Back out lock down screws. Unseat tbg hanger staging up to 65K before unseating.Continue to pull seals free @ 75K,before string wt falling to 50K up wt. PU hole 15'with 50K Up wt. Monitor well with 23 BPH static loss rate. Close bag and CBU @ 3 BPM 240 PSI with 193 max gas units.Open up to flow line and circulate additional 20 bbls. Monitor well with 25 BPH static loss. Pull tubing hanger to floor. Undress hanger from control lines. Lay down tubing hanger. Break down and lay down 4" Drill Pipe Landing joint. Drain and blow down choke manifold. Blow down Top Drive. POOH laying down 2 7/8 Gas Lift completion. Hilcorp Alaska, LLC Elikorp,tla.k,,.LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-03RD3 50-733-10057-03 197-130 2/3/2015 2/9/2015 02/05/15-Thursday Continue pooh cleaning and L/dn 2-7/8"6.5#,8rd gas lift completion w/complete recovery t/seal assy. No abnormal or norm above back ground found. Clean/Clear/Floor/Door. L/dn power tongs and tbg handling equipment. Rig housekeeping through out.Set wear ring(Static loss rate @ 20 bph). PJSM. P/up BHA#1-Bowen"C" Dim spear(dressed w/3.198" nom catch grapple), XO,XO,4-3/4"bumper sub,4-3/4"oil jar,pump out sub,(9)4-3/4"dc's,4-3/4"Acc jar,XO=317.65'.Chg out TDS gripper dies. Daily fluid loss=585 bbls 3%8.6 KCL. Total Fluid Loss to Well=1187 bbls 3%8.6 KCL. Average Daily Loss Rate=24.4 BPH.Sized Salt Pill=40 bbls.Total Sized salt=80 bbls.Annulus Pressures:20"=0, 13 3/8"=133 psi, 9 5/8"'=180 psi. RIH w/BHA#1 on DP t/2,305'. Kelly up and fill pipe @ 2 bpm,620 psi. Establish parameters up/dn 71/66k. Circ Btm/up @ 4 bpm @ 2250 psi w/max 3 units gas. Circ @ 2 bpm @ 620 psi.Tag PBR @ 2,368'and engage t/2,371'w/15k dn. P/up bleed jars and set grapple @ 20k over. P/up prk released @ 50k over w/3k drag t/2,350'. Circ btm up w/high gas units t/431 units,continue circ 3 complete rounds w/ gas trending dn t/23 units.Obtain static loss rate @ 20 bph Blow dn TDS. Pooh slow w/prk assy with no issues. Had full recovery of PKR. Lay down PKR and BHA. MU BHA#2-Scraper/Clean out as follows:6"OD Mill Tooth Bit, Boot Basket,7"Casing Scraper, 3)Boot Baskets, Bit Sub with float, Bumper sub,Oil Jar,String Magnet, Pump out sub,9)4 3/4" DC's,Accl Jar,XO to HT-38.Total BHA Length=344.92'. TIH from 344'to 2,450'. PJSM.Slip and cut 124'Drill line. TIH with C/O assy on 4" DP from derrick from 2,450'stopping to reciprocate and circulate bottoms up at 3,450,4,450 5,560,6,230,7,331,circulating @ 14 BPM. Max Gas @ 500 units from 7,330'. Did not tag any fill or obstructions from 2,450'to 7,330'. Had slight traces of sand/oil @ all bottoms up circulations. Losses to well averaging 40 BPH while circulating 14 bpm. Continue to TIH picking up 4" DP from catwalk from 7,330'. Tag fill @ 8,105'.220K Up Wt,95K Dn Wt. MU Top Drive and wash down from 8,105'to 8,134'@ 10 bpm 2100 psi,5-10K Dn wt. Start stacking wt @ 8,134'.Attempt to wash past 8,134'with no success.CBU x 2 from 8,134'with 477u max gas and small amount of sand. Loss rate at 35 BPH while circulating. Lay down single. Blown down TDS. Monitor well with 12 BPH Loss rate. POOH laying down 4" Drill pipe from 8,134'to 7,550'. 02/06/15-Friday Continue Pooh. L/dn 4" DP work string t/BHA#2. Rack back 3 std 4" DP and 3 std 4-3/4" DC's.Clean Junk bsk(mt)and string magnet @ 7.5#iron and L/dn BHA. Daily fluid loss=332 bbls 3%8.6 KCL.Total Fluid Loss to Well=1519 bbls 3%8.6 KCL. Average Daily Loss Rate=13.8 BPH.Sized Salt Pill=0 bbls.Total Sized salt=80 bbls.Annulus Pressures:20'=0, 13 3/8"=133 psi, 9 5/8"' =180 psi. Monitor static well at 12-14 bph loss rate.Spot new tbg spool in well room.Work on spool bolts. Continue monitor static well 12-14 bph.Continue work on bolts for spool chg/out. Prep tools&equipment for spool chg/out&nip/dn.Continue wait on boat/weather for back load of DP and potable water. PTSM with new drill crew. Pick up HOWCO RTTS w/Storm valve on top of 9)4 3/4' DC's.RIH 3 stands and set RTTS @ 283'. POOH stand back drill pipe.Test storm valve to 1500 psi. Pull master bushings,vac out drip pan,pull flow riser and air boot flange on top of bag. R/U BOPE. Pick Up Slings to Stack. N/D and remove CIW DCB Tbg spool. Land and N/U CACTUS 11 5M Tbg Spool and Test void t/2500 psi for 30 min(ok). Land drilling riser. NU BOPE and associated equipment. Clean up all work areas associated with tbg spool change out.Wellhead room,cellar and rig floor area. Land Test plug and shell test BOPEbreaks to 250 2500 psi.on chart. RIH with 3 stands drill pipe and release RTTS.Could not fully engage stinger. MU top Drive and circulate on top of storm valve to clear any debris from tool top.Sting in and release RTTS taking, 12 bbls to fill below RTTS. • Hilcorp Alaska, LLC IIiI4.urpAlaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-03RD3 50-733-10057-03 197-130 2/3/2015 2/9/2015 02/07/15-Saturday Circ around remove oil cap. Blow dn TDS.Monitor Static well @ 17 bph loss rate. Pooh L/dn Last 4" DP and L/dn chk BHA(ok). Running at diminished capacity waiting on boat/weather to back load DP to boat.Clear clean floor.Service rig. Monitor static well @ 15 bph loss rate. Daily fluid loss=326 bbls 3%8.6 KCL.Total Fluid Loss to Well=1845 bbls 3%8.6 KCL. Average Daily Loss Rate =13.5 BPH.Sized Salt Pill=0 bbls.Total Sized salt=80 bbls.Annulus Pressures:20'=0, 13 3/8"=133 psi, 9 5/8"'=180 psi. Loss rate @ 12-14 bph. Rig maintenance. P/up rabbit RIH w/61 jts RR 2-7/8"L-80 6.5#8 rd tbg on deck and m/up w/36"pipe wrench. Boat was able to stop by w/106 jts new 2-7/8"6.5#8rd tbg. But no back load yet(we are packed-off with bundles of pipe). Install safety valve w/WLRG @ 1,861'. Continue p/up rabbit new tbg 2-7/8" L-80 6.5#8 rd. M/up rough neck tight w/36"pipe wrench. PU 101 JTS new and 61 jts RR tubing for total of 162 jts=5,107'. Install head pin @ w/162 total jts p/up w/WLRG @ 5,107". Circulate hole volume @5 BPM, 1000 psi with 432 units gas @ bottoms up.Wait on boat w/tong hand. Rig Maintenance. Monitor loss rate @ 11 bph. Rig up Weatherford tubing handling equipment. Pooh racking back tubing and torque connections to specs. Platform lost power.Space out and install FOSV.Stand by for Production. Continue to Pooh racking back tubing and torque connections to specs. Clean and clear rig floor and prep to RU and run ESP Completion. Monitor loss rate @ 12 bph. 02/08/15-Sunday Continue prep and r/up to run ESP assy.Static loss @ 12 bph. P/up,build and service in hole Summit ESP assy. Loss @+/-12 bph. Daily fluid loss=364 bbls 3%8.6 KCL.Total Fluid Loss to Well=2109 bbls 3%8.6 KCL. Average Daily Loss Rate=11 BPH.Sized Salt Pill=0 bbls.Total Sized salt=80 bbls.Annulus Pressures:20'=0, 13 3/8"=133 psi, 9 5/8"'=180 psi. RIH slowly with SUMMIT ESP Assy on 2 7/8"tubing from derrick from 136'to 4,950'taking extra care and minimizing pipe movement through DLS depths. Installed clamps every connection and mid joint to 1,800'(108 jts).Total clamps from bottom to 413'(PKR Top)=281'.(19 mtr clamps)(1 Splice Clamp)(261 Cannon Clamps.)Meg cable at maximum 1,000'intervals or as needed. Loss rate @ 11.7 BPH. PU Tri Point 7" PKR Assy. Mark and cut ESP cable. Pass ESP cable through PKR Body. Make field splice on ESP Cable. 02/09/15-Monday Continue perform prk splice&dress prk w/chemical lines and vent valve and meg test splice(ok). Function test vent valve.Starts open @ 1400 psi&fully open @ 2400 &pressure tested t/2500 for 5 min(ok).Pressure test chemical lines t/5000 psi(ok). Loss rate @ 11 bph. Continue RIH w/2-7/8"tbg from derrick,installing cannon clamps on every conn. Meg test(ok). Install SSSV, function test same&pressure test t/5000 psi 5 min(ok). Continue RIH w/2-7/8"tbg from derrick,installing cannon clamps on every conn. M/up landing jt and tbg hanger&orient same. Meg test(ok). Perform penetrator splice and meg,ok. Dress hanger w/ chemical lines and test same t/5000 psi(ok)and plug same. Dress SSSV control line and pressure test same t/5000 psi(ok). Function test Vent line(ok). Land hanger w/Anode @ 5,381'RILDS and test communication w/gauge(ok). Daily fluid loss=364 bbls 3%8.6 KCL.Total Fluid Loss to Well=2109 bbls 3%8.6 KCL. Average Daily Loss Rate=11 BPH.Sized Salt Pill=0 bbls.Total Sized salt=80 bbls.Annulus Pressures:20'=0, 13 3/8"=133 psi, 9 5/8"'=180 psi. Drop bar/ball r/up pumping lines attempt pressure up w/#2 mud pump t/3800 psi. Pump tripped out @ 2900 psi(seen prk shift @ 1400 psi).Bleed off pressure.Attempt pressure up w/#1 mp @ 2800, pump stalled out. Bleed off. R/up test pump,pressured up t/2000 with MP and finish w/test pump t/3800 psi and hold for 30 min. Bleed off pressure and r/up pump lines t/annulus&pressure up 9-5/8"X tbg annulus against prk @ 413'w/sssv and tbg open t/1500 psi for 30 min on chart w/no bleed off(good)Bleed dn.R/dn sheaves in derrick. Blow dn R/dn lines. L/dn landing jt&set BPV and R/dn Tbg handing equipment.Clean and organize floor. Prep for N/D of BOPE. N/D BOPE/Drilling Riser and associated Equipment. Up Weight=82K,Down Weight=63K,Weight on Hanger=30K.Total Clamps: =294:(19 Motor Clamps).(1 Splice Clamp)(274 Cannon Clamps).Total Bands:=9:(5 on PKR)(2 on SSSV)(2 on Hanger). Land and N/U Tree and wing section.Pull BPV.Set TWC.Test Tbg Hgr void to 250/5000 psi.Test tree and wing valves to 250/5000 psi.Pull TWC.Finish dressing control lines. Pump open SSSV and hold 4800 psi. RU Slick Line. RIH and retrieve Ball/Rod. Ease through SSSV with no issue on RIH or POOH. RIH and retrieve RHC. Rig down Slick Line.Turn Well over to Production. Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. I~-I~O File Number of Well History File PAGES TO DELETE Complete RESCAN ~Color items - Pages: n Grayscale, halftones, pictures, graphs, charts - Pages: n Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [3 Diskettes, No. [3 Other, No/Type OVERSIZED [3 Logs of various kinds D Other COMMENTS: Scanned by: eev~y Mildred D'amtha t~owell TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Damtha Nathan Lowell Date: /s/ • I �� \\ %%/ s 9 �� and Gas w THE STATE K Gil f d ns ry i Commission - .ice gritt GOVERNOR SEAN PARNELL 333 West Seventh Avenue 94"ALAS� Anchorage, Alaska 99501 -3572 Main: 907.279.1433 Fax: 907.276.7542 Ted Kramer SCANNED JUN 2 4 2013 0 Sr. Operations Engineer ' O 1 Hilcorp Alaska, LLC 3800 Centerpoint Drive Anchorage, AK 99503 Re: Trading Bay Field, Hemlock Oil Pool, Trading Bay ST A -03RD3 Sundry Number: 313 -289 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, P _,;(4 z e Cathy P. F erster Chair DATED this 4-4 day of June, 2013. Encl. • • <' ` ,ry � � z �I �3 ., STATE OF ALASKA 11 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY A `, , ; �4 ' 20 MC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pod ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate I] . Pug Tubing El Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. Hilcorp Alaska, LLC Exploratory ❑ Development El v 197 -130 ' 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number. Anchorage, AK 99503 50- 733 - 10057 -03 - 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order govems well spacing in this pool? CO93 Will planned perforations require a spacing exception? Yes ❑ No El Trading Bay ST A-03RD3 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0018731 Trading Bt 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): 8,525 7,213 8,417 7,121 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 277' 20" 277' 227' Surface 1,739' 13 -3/8" 1,870' 1,739' 3,090 psi 1,540 psi Intermediate Production 3,500' 9 -5/8" 3,500' 3,045' 6,870 psi 4,760 psi Liner 8,510' 7" 8,510' 7,200' 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 2 -7/8" 6.4# L -80 5,506' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): HES Packer / SSSV: N/A • Pkr 5,328' (MD) / 4,553" (TVD) and SSSV:N /A 12. Attachments: Description Summary of Proposal 0 , 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El • Exploratory ❑ Stratigraphic ❑ Development S • Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 6/28/2013 Commencing Operations: 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 tkramer(a2hilcorp.com Printed Name Ted Kramer Title Sr. Operations Engineer Signature ,<r/-'a Phone 907 777 -8420 Date 6/7/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test C Mechanical Integrity Test ❑ Location Clearance ❑ Other: if z 5 I DS t. /S s /--- ) RBDMS JUN 21 2013 Spacing Exception Required? Yes ❑ No I/ Subsequent Form Required: /0 - y ray APPROVED BY Approved b /../A__....-- COMMISSIONER THE COMMISSION Date: /3 Submit Form and � ``�\ Form 10-403 (Revised 10/2012) App D VV ipli l NAL months rom the date of approval. Att chments in Duplicate `� \ \` 46:4;0_,, • • Well Prognosis Well: A -3 RD3 Hilcorp Alaska, LL, Date: 06/07/2013 Well Name: Monopod A -3 RD3 API Number: 507331005703 Current Status: Oil producer (Gas Lifted) Leg: N/A Estimated Start Date: June 28, 2013 Rig: Monopod Rig #56 Reg. Approval Req'd? 10 -403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett 777 -8332 Permit to Drill Number: 197 -130 First CaII Engineer: Ted Kramer (907) 777 -8420 (0) (985) 867 -0665 (M) Second Call Engineer: Trudi Hallett (907) 777 -8323 (0) AFE Number: Current Bottom Hole Pressure: 2,150 psi @ 6,903' (5,840' TVD) Calculated From 1997 pressure survey. Maximum Expected BHP: 2,804 psi @ 7,670' MD (6,477' TVD) assuming virgin, naturally pressured reservoir. Max. Anticipated Surface Pressure: 1,503 psi. (Using Worst case scenario of all gas in tubing from 5,362' ( 4,514 TVD) to surface and a .1 psi /ft. gas gradient. Brief Well Summary The A -3 is currently completed as an gas lifted oil well. The most recent well test shows that the well makes 20 bopd and 3 bwpd. This well was last worked on in 1997. The re- completion plan involves pulling the existing completion, cleaning out to the PBTD at 8,417 and then perforating / re- perforating the well. A new completion string will then be ran which will consist of an SSSV, GLMs, and a completion packer. The well will then be placed back on Gas lift and produced. Brief Procedure: 1. MIRU Monopod Platform Rig # 56. • 2. RU E -line and RIH with tubing punch and punch circulation holes at 5,320'. ° 3. Circulate three percent KCL to kill well and to circulate Hydrocarbon off of the well. • 4. ND Wellhead, NU BOP and test to 250psi low /2,500 si hi h. (Note: Notify AOGCC 24 hours in advance of test to allow them to witness test). °l 5. RU a -line and RIH with tubing cutter to 5,322' ( + / -). Unseat Hanger and pick up on tubing. Cut tbg. RD E -line. 6. POOH laying down production tubing. 7. PU 5" DP Workstring with 2 -7/8" grapple and overshot. Engage TOF @ 5322' + / -. Work tubing and release HES PHL Packer (54,600# over string weight to release). POOH with same. 8. PU Clean out assembly for 7" 29# casing and RIH cleaning out to PBTD (8417'). PU and circulate clean. POOH. 9. RU E -line company. RIH with GR / CCL log to 8,400'. Log out of hole to 3,500'. POOH with logging tool. RD E -line. 10. PU Test Packer. RIH to 3725' and set. Pressure up back side and pressure test casing to 1,600 psi for 30 min. Chart same. POOH with Test Packer. 11. RU TCP perforating Company. PU perforating guns and RIH spacing out according to GR log and the Final Approved Perforation Request Form Dated 2/8/2013'. Fire Guns. • • Well Prognosis Well: A -3 RD3 Hilcorp Alaska, LL Date: 06/07/2013 12. Circulate out Perf gas and monitor fluid level and fluid Toss for 1 hr by shooting fluid levels. Once well is stable, POOH with TCP guns. 13. RU E -line. RIH and set Model D permanent packer at 3,520' ( + / -). RD E -line. 14. PU new completion consisting of Seal Assembly, GLMs, and SSSV spaced out on a 2 -7/8" production tubing string and hang off same. ` . '� f �o / J " io 5 . 15. ND BOP, NU wellhead and test. 16. Turn well over to production. Attachments: 1. As -built Well Schematic 2. Proposed Well Schematic 3. BOP Drawing • • SCHEMATIC MONOPOD PLATFORM WELL # A -3RD3 API# 50- 733 - 10057 -03 Completed 7/20/97 KB = 101' RKB from MSL CASING AND PLUG DETAIL SIZE WT GRADE CONN ID TOP BOTTOM 1 j - - I.) 20" 0 277' 2 _ #I.)= IrE ¥ J-5 16444 ® 3= III.) 13 -3/8" 61 J -55 12.515 0 1870' I 3 -"\-J IV.) 9 -5/8" 47 N -80 8.681 0 3500' (KOP) V.) 7" 29 L -80 6.184 0 8510' Tubing II ' 4 ---J 2 -7/8" 6.4 N -80 Buttress 2.441 0 5403' Tbg Up wt = 42,000# Down Wt = 32,000# Field inspection does not find 16" casing 11/2003 JJD 5 - 10/3/05 Tag Fill @ 8,148 III TUBING DETAIL 6 �J Item MD Min ID Description 1. 39.23' Hanger 2. 326' 2.313 HES 2.313" "XXO" SVLN IV ' 3. 2330' 2.347 McMurry SMO -2, 1 -1/2" GLM 4. 3301' 2.347 McMurry SMO -2, 1 -1/2" GLM 5. 3951' 2.347 McMurry SMO -2, 1 -1/2" GLM _ 7 � J 6. 4416' 2.347 McMurry SMO -2, 1 -1/2" GLM 7. 4877' 2.347 McMurry SMO -2, 1 -1/2" GLM 8. 5273' 2.347 McMurry SMO -2, 1 -1/2" GLM 9. 5318' 2.313 HES "XU" Dura Sldg Sive 8 J 10. 5328 2.380 HES 7" "PHL" PACKER, Releases @ 54,600# 11. 5 2.313 HES "X" LANDING NIPPLE O 12. 5403' 2.441 WLRG 10 E E Perforation Detail 11 Zone Top Bottom Amount SPF Date Comments C 5,420' 5,440' 20' 6 8/15/1997 2 -1/8" 0 degree Phased Strip Guns C 5,490' 5,520' 30' 6 8/15/1997 2 -1/8" 0 degree Phased Strip Guns 12 / , C 5,555' 5,620' 65' 6 8/15/1997 2 -1/8" 0 degree Phased Strip Guns C 5,795' 5,960' 165' 6 8/15/1997 2 -1/8" 0 degree Phased Strip Guns C 6,050' 6,168' 118' 6 8/15/1997 2 -1/8" 0 degree Phased Strip Guns C 6,203' 6,275' 72' 6 8/15/1997 2 -1/8" 0 degree Phased Strip Guns C 6,285' 6,350' 65' 6 8/15/1997 2 -1/8" 0 degree Phased Strip Guns C 6,382' 6,402' 20' 6 8/15/1997 2 -1/8" 0 degree Phased Strip Guns C 6,528' 6,538' 10' 6 8/15/1997 2 -1/8" 0 degree Phased Strip Guns C 6,978' 7,018' 40' 11 7/20/1997 4 -1/2" Csg Guns, 5spf, 30 deg phased C 7,055' 7,077' 22' 11 7/20/1997 4 -1/2" Csg Guns, 5spf, 30 deg phased C 7,160' 7,182' 22' 11 7/20/1997 4 -1/2" Csg Guns, 5spf, 30 deg phased C 7,382' 7,422' 40' 11 7/20/1997 4 -1/2" Csg Guns, 5spf, 30 deg phased C 7,446' 7,480' 34' 11 7/20/1997 4 -1/2" Csg Guns, 5spf, 30 deg phased C 7,690' 7,756' 66' 6 5/12/1997 2 -1/8" 0 degree Phased Strip Guns C 7,803' 7,836' 33' 6 5/12/1997 2 -1/8" 0 degree Phased Strip Guns C 7,884' 7,917' 33' 6 5/12/1997 2 -1/8" 0 degree Phased Strip Guns - V / \ C 8,042' 8,075' 33' 6 5/12/1997 2 -1 /8" 0 degree Phased Strip Guns MAX HOLE ANGLE = 40° C 8,207' 8,240' 33' 6 5/12/1997 2 -1/8" 0 degree Phased Strip Guns C 8,270' 8,303' 33' 6 5/12/1997 2 -1/8" 0 degree Phased Strip Guns PBTD =8417' C 8,320' 8,386' 66' 6 5/12/1997 2 -1/8" 0 degree Phased Strip Guns TD = 8525' ' Updated by: JLL 05 -24 -13 1 1 • • Trading Bay Unit PROPOSED Well: A -3RD3 Hilcorp Alaska, LLC Completed: 07/20/97 KB CASING AND PLUG DETAIL B = 101' RKB from MSL SIZE WT GRADE CONN ID TOP BOTTOM 1 - I.) 20" 0 277' 2 46 W4 #§5 0 4 2D" III.) 13 -3/8" 61 J -55 12.515 0 1870' IV 9 5/8" 47 N -80 8.681 0 3500' (KOP) V.) 7" 29 L -80 6.184 0 8510' 16" Tubing • I 2-7/8" 16.4 L -80 8rd 0 ±3,552' Tbg Up wt = 42,000# Down Wt = 32,000# TUBING DETAIL 13 -3/8" , Item MD Min ID Description • 1 39.23' Hanger 2 ±300' SSSV 3 3 ±2,319' GLM 4 ±3,443' GLM 5 ±3,520' Packer w /Seal Assembly 6 ±3,551' X Nipple 7 ±3,552' WLRG Field inspection does not find 16" casing 11/2003 JJD 9 - /8" Si 1 4 10/3/05 Tag Fill @ 8,148 A in • II= 5 Perforation Details -„ 6 _ 1 Zone Top Bottom Top Bottom Amount SPF Date Comments B (MD) (MD) (NDI (ND) B ±3,570' ±3,735' ±3,100' ±3,230' 165' Future B ±3,784' ±3,860' ±3,268' ±3,329' 76' Future 7 = l B ±3,978' ±4,026' ±3,425' ±3,465' 48' Future B ±4,102' ±4,200' ±3,528' ±3,608' 98' Future _ B ±4,605' ±4,720' ±3,946' ±4,043' 115' Future C ±4,730' ±4,816' ±4,052' ±4,124' 86' Future C ±4,838' ±5,262' ±4,143' ±4,498' 424' Future C ±5,404' ±5,444' ±4,616' ±4,649' 40' Future C 5,420' 5,440' 4,629' 4,645' 20' 6 8/15/1997 2 -1 /8" 0 degree Phased Strip Guns C ±5,470' ±5,618' ±4,670' 34,791' 148' Future C 5,490' 5,520' 4,686' 4,711' 30' 6 8/15/1997 2 -1 /8" 0 degree Phased Strip Guns C 5,555' 5,620' 4,739' 4,792' 65' 6 8/15/1997 2 -1 /8" 0 degree Phased Strip Guns C ±5,760' ±5,875' ±4,905' ±4,997' 115' Future C 5,795' 5,960' 4,934' 5,065' 165' 6 8/15/1997 2 -1/8" 0 degree Phased Strip Guns C ±5,890' ±5,955' ±5,009' ±5,093' 65' Future C ±6040' 36,167' ±5,129' ±5,234' 127' Future C 6,050' 6,168' 5,137' 5,235' 118' 6 8/15/1997 2 -1/8" 0 degree Phased Strip Guns C 6,203' 6,275' 5,264' 5,324' 72' 6 8/15/1997 2 -1 /8" 0 degree Phased Strip Guns C ±6,225' ±6,400' 35,282' ±5,427' 175' Future W. C 6,285' 6,350' 5,332' 5,386' 65' 6 8/15/1997 2 -1 /8" 0 degree Phased Strip Guns C 6,382' 6,402' 5,412' 5,429' 20' 6 8/15/1997 2 -1/8" 0 degree Phased Strip Guns c C ±6,519' ±6,546' ±5,526' ±5,549' 27' Future _ C 6,528' 6,538' 5,534' 5,542' 10' 6 8/15/1997 2 -1/8" 0 degree Phased Strip Guns C ±6,962' ±7,022' ±5,889' ±5,938' 60' Future C 6,978' 7,018' 5,902' 5,935' 40' 11 7/20/1997 4 -1/2" Csg Guns, 5spf, 30 deg phased C ±7,052' ±7,078' ±5,963' ±5,984' 26' Future - C 7,055' 7,077' 5,965' 5,983' 22' 11 7/20/1997 4 -1/2" Csg Guns, 5spf, 30 deg phased C 7,160' 7,182' 6,051' 6,069' 22' 11 7/20/1997 4 -1/2" Csg Guns, 5spf, 30 deg phased C ±7,160' ±7,190' ±6,051' ±6,075' 30' Future C ±7,350' ±7,489' ±6,207' ±6,323' 139' Future C 7,382' 7,422' 6,234' 6,267' 40' 11 7/20/1997 4 -1/2" Csg Guns, 5spf, 30 deg phased C 7,446' 7,480' 6,287' 6,316' 34' 11 7/20/1997 4 -1/2" Csg Guns, 5spf, 30 deg phased C ±7,610' ±7,670' ±6,427' ±6,478' 60' Future C 7,690' 7,756' 6,495' 6,552' 66' 6 5/12/1997 2 -1/8" 0 degree Phased Strip Guns s C ±7,698' ±7,850' ±6,502' ±6,634' 152' Future C 7,803' 7,836' 6,593' 6,622' 33' 6 5/12/1997 2 -1 /8" 0 degree Phased Strip Guns C 7,884' 7,917' 6,663' 6,692' 33' 6 5/12/1997 2 -1/8" 0 degree Phased Strip Guns C ±8,022' ±8,055' ±6,782' ±6,810' 33' Future C 8,042' 8,075' 6,799' 6,827' 33' 6 5/12/1997 2 -1 /8" 0 degree Phased Strip Guns = C ±8,192' 38,260' 8,207' 8,240' ±6,928' ±6,896' 68' Future C 6,940' 6,969' 33' 6 5/12/1997 2 -1/8" 0 degree Phased Strip Guns 7 " C ±8,266' ±8,310' ±6,991' ±7,029' 44' Future C 8,270' 8,303' 6,994' 7,023' 33' 6 5/12/1997 2 -1 /8" 0 degree Phased Strip Guns Max Hole Angle = 40° C ±8,318' ±8,386' ±7,036' ±7,094' 68' Future PBTD = 8,417' C 8,320' 8,386' 7,037' 7,094' 66' 6 5/12/1997 2 -1/8" 0 degree Phased Strip Guns TD = 8,525' Revised By: JLL 06 -06 -2013 • • • Monopod Platform A -3RD3 Current 05/23/2013 Hilrnrp ;Uarka,1,1.1, Monopod Tubing hanger, CIW -DCB, A -3RD3 11 X 2 7/8 IBT lift and 13 3/8 X A-3RD3 7 X 2 7/8 2 7/8 IBT susp, w/ 2 1/2" type H BPV profile, 6''A" EN, 'A" non continuous control line BHTA, Bowen, 2 9/16 5M X 2'A Bowen Union I - WE Valve, Swab, WKM -M, _ ,c ,(111 — 2 9/16 SM FE, HWO, DD trim II II Valve, Upper Master, CIW -F, . o � 2 9/16 5M FE, HWO, DD trim ' '4 r o�' lir ,,� .. Valve, Master, CIW -F, to r © . 2 9/16 5M FE, HWO, DD trim c` Alm. Adapter, CIW, 11 5M FE X till inn 2 9/16 5M, w/ 6'''A pocket and 'A npt control line exit ' .-- 7 - _ Tubing head, CIW -DCB, = ,; i ;,_ 13 5/8 3M X 11 5M, w/ 2- , — ill Valve, CIW-FC, 2 1/16 5M FE, 2 1/16 SM EFO, X- bottom VR profile prep w/ 1 , f ` ,6:.) HWO, AA 'A II Ili . . I 11 -I, is! I III Casing spool, McEvoy -SL, "°' 1111 I I. `°` • 13 5/8 3M X 13 5/8 3M, iii — I l I Valve, CIW -FC, 2 1/16 5M FE, w/ 2- 2 1/16 5M 550 j p i HWO, AA al :IW2 Casing head, Shaffer -KD, 13 5/8 3M X 13" SOW r, bottom, w/ 2" LPO III J iii IM 1 In �,�� 2 "LP plug valve w O . • Monopod Platform 2013 BOP Stack Hileurp Alaoka, 1.1 03/12/2013 .C, Rig Floor Bottom of air boot Range I k, I !I 5' below rig floor 14.72' 9.s0' I ie11LIII:IIIIii • I I I I 3.74' Shaff i ill lii Iii Ill Ill 26.25 Shaffer LXT 2 7/8 -5 Variables _� - RR 2.50' 13 5/8 SM 11-1 : __ Blind It_I 111111111 lii r r� 1.76 11 1 11 1 1 1 � ' }Ili Mud Cross • : s416:44i ` Ili I l ' 135/85M FEXFE ql=r w/ 31/8 5M EFO w/ 2 1/16 5M Choke and Kill valves w/ Unbolt end connections for lines III Ii! 111 Iil It: 2.83' Dual Cameron Flex rams ill Ill 111111 !1! .70' 111 11 I 1 ":1 V Drill deck Riser 14.20' 135 /85M FE X 135/85M FE 111 :i: II " i! ill IIP'i! ill il:' 111 Spacer spool 1.5' 135/85M FEX113M II I, Wellhead @ 15.00' • • c ''''T A ' SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 April 6, 2012 Mr. Chris Myers Field Superintendent Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524 -4027 RE: No -Flow Verification Trading Bay State A -03RD3 S,NNED APR tl L "- 1' PTD 1971300 Dear Mr. Myers: On March 14, 2012 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no -flow test of Trading Bay State A -03RD3 located on the Monopod 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 Hilcorp verified no obstruction exists in the wellbore, the well was shut in, and calibrated flow measurement equipment with suitable range and accuracy was installed. The Trading Bay State A -03RD3 was monitored for flow for 3 hours through calibrated flow measurement equipment. During the flow monitoring periods, less than 180 standard cubic feet per hour was measured. There was no measurable liquid production to surface. The subsurface safety valve must be returned to service if Trading Bay State A -03RD3 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 Monopod Platform. Sincerely, QAAkkdg -el James B. Regg Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg \ `� 4 L DATE: March 14, 2012 P.I. Supervisor 1 l FROM: Jeff Jones SUBJECT: No -Flow Test Petroleum Inspector Hilcorp Alaska LLC Trading Bay State A -03RD3 - PTD 1971300 - Monopod Platform March 14, 2012: I traveled to Hilcorp's Monopod Platform in Cook Inlet to witness a No -Flow Test on well A- 03RD3. On my arrival on the platform I met with Hilcorp Lead Operator Greg Geller and we discussed the operational details of the test. Mr. Geller indicated that the well pressure had been bled down and the wellbore perfs were open to the tree cap with no plugs or restrictions. Well A -03RD3 was lined up from the tree top swab valve through an Armor -Flow model # 3461 -03T0 flow meter (180 SCFH to 1800 SCFH span) to a 1" hose which terminated in an open top drum. The flow from the well was monitored for 3 hours with readings recorded every 30 minutes. Unassisted gas and liquid flow from the well did not exceed 900 cubic feet gas per hour or 6.3 gals liquid per hour flow rate during the test. Well A -03RD3 meets the AOGCC requirements for a No -Flow status determination. - Summary: I witnessed a successful No -Flow Test on Hilcorp's Trading Bay State A -03RD3 on the Monopod Platform. - Well No -Flow Test Data Operator: Hilcorp Alaska LLC Operator Rep: Greg Geller AOGCC Rep: Jeff Jones Field /Unit/Pad TBF / Monopod PLT Well: A -03RD3 Time - Well Flow Comments Gas Liquid 8:30 < 180 scfh none Start Test 9:00 < 180 scfh none 9:30 < 180 scfh none 10:00 < 180 scfh none 10:30 < 180 scfh none 11:00 < 180 scfh none 11:30 < 180 scfh none End Test Produced to open top container through Armor -Flow meter model #3461- 03T0 -13 ser. # 112377 - Total liquid produced: no significant amount. Attachments: none # APR 2U1 RJF 09/19/02 Page 1 of 1 2012-03 14 No- Flow _Trading_Bay_State_A- 03RD3Jj Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 T¢le: (907) 263-7651 Fax: (907) 263-7828 E-mail: harrisonb~unocal.com UNOCAL Beverly Harrison Business Ventures Assistant May 30, 2002 To: Lisa Weepie AOGCC 333 W. 7th Ave. Anchorage, AK 99501 DATA TRANSMITTAL- Alaska / Offshore / Monopod Platform Dry Samples A-3RD 2 3492'-4890' 4890'-6210' 6210'-7262' Box 1 of 3 Box 2 of 3 Box 3 of 3 A-3RD 3 A-8RD A-27RD 5980'-7240' 7240'-8350' 8350'-8525' 3440'-4510' 4510'-5590' 5590'-6850' 6880'-7641' 8460'-9600' 9600'-10710' 10710'-11640' 11640'-12660' 12700'-12900' Box 1 of 3 Box 2 of 3 Box 3 of 3 Box 1 of 4 Box 2 of 4 Box 3 of 4 Box 4 of 4 Box 1 of 5 Box 2 of 5 Box 3 of 5 Box 4 of 5 Box 5 of 5 Dry Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. Received By: ~ ~Jfi-~ Date: ~'~~") '~ MEMORANDUM TO: THRU: Julie Heusser, Commissioner Tom Maunder, ~3'~ P. !. Supervisor o~lo~,'° \ State of Alaska Alaska Oil and Gas Conservation Commission DATE: April 5, 2001 FROM: Jeff Jones, SUBJECT: Petroleum Inspector Safety Valve Tests Monopod Platform Trading Bay Field T.hursd.ay, April 5, 200!: I traveled to UNOCAL's Monopod Platform and witnessed the semi annual safety valve system testing. Lead operator Gary Smith conducted the testing today; he did a thorough job and was a pleasure to work with. As the AOGCC Safety Valve System test report indicates ! witnessed the testing of 18 wells and 53 components, with four failures. The pilot on well A-02 tripped at 26 psi and was repaired and passed a retest. This well has had the SSSV removed for repair since 2/24/00 and has not been re-installed. Well A-11 has had the SSSV removed for repair since 11/7/99 and has not been re-installed. ! indicated to Mr. Smith that these SSSV's must be repaired and re-installed and successfully tested in a timely manner or the two wells shut in. Well A-06 SSSV failed to close and will require maintenance. Wells A-13 and A-21 have been certified as "no flow" status and do not have SSSV's installed. While on location ! inspected the platform and found it very clean and it appeared to be in excellent condition. Summary.: i witnessed the semi annual Safety Valve System testing at Unocal's Monopod Platform in the Trading Bay Field. Monopod Platform, 18 wells, $3 components. 4 failures, 7.5% failure rate. ~Platform inspection conducted. Attachment: SVS TBF Monopod Platform 4/5/01 JJ NON-CONFIDENT,IAL, SVS TBF Monopod Platform 4-5-01 JJ Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: UNOCAL Operator Rep: Gary Smith AOGCC Rep: Jeff Jones Submitted By: Jeff Jones Date: Field/Unit/Pad: Trading Bay ,Field Monopod Separator psi: LPS 65 HPS 4/5/01 i Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI pSI Trip Code Code Code Passed GAS or CYCLE PD i i I I I I I ~ ii 90'1470 A42" 1660490 ' 65 45 26 3' P -'-43' 4/5/01 " OIL ~:03~3'-:' .._!?~,71300 65! 45 42 P ' P P~ OIL! ~:04 -- 1670020 A-06 1670250 65 45 " 45 P P ~43 0IL A-07 1670460 65! 45 '42 P e e '0IL , , A-09RD 1810360 A- 10 1670760 ~A-1t ' 1700240 ' 65 ~5 '43 P ' e z[3 0IL A-13 1680020 65 45 41 e e OIL A. 14 " 1680270 ..... A-15 '1680330 65 45 45 P 'J P P ' OiL A-16RD " 1880380 65 45 41/42 P '1; 'P ....... OIL A-I'7RD 1810670 65 45 43 e' e P '" OIL A-18 ' 1~0760 6~ "~5 ' 47" P e i~ ' ' ' OIL A-21 1700470 65 45 46 P P OIL A-22 17003 i0 ' 65 45 44 P P P ' OIL , , A.23 1700590 A-23DPN 1720200 A-24RD 18i0400 65 45" 4'1 P P P " oIL , , , A-27RD1 1970630 65 45 . ,43 i, P P' P ,OIL A'28RD 1890920 65 " 45 45 e e P OIL A-30 1730140 ,A-32 1770180 ~5 45 44 P P P OIL , Wells: 18 Components: 53 Failures: "~4 Failure Rate: 7.5% Flg0Dav A-13 & A-21 reported as No-Flow wells. Remarks: SSSV's removed for repair: A-02 out since2/24/00, A-11 out since 11/7/99. A?02 pilot rep ,a~r, ed and retested "OK". A-06 SSSV failed to close. A- 16 RD is a dual complet!oru .... 4/9/01 Page 1 of 1 SVS TBF Monopod Platform 4-5-01 JJ THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE M P L ATE E IA L U N D W E R T H IS M A R K E R C:LOR1XMFILM.DOC PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: 1 Date: 05/24/99 RUN RECVD 97-130 SRXrY LSTNG 97-130 CMT BOND V~_RI 97-130 TDTP 97-130 TDTP 97-130 PEX-AIT/GR 97-130 PEX-AIT/GR 97-130 JUNK 97-130 PEX-LDT/N 97-130 PEX-LDT/N 97-130 COMP RED 97-130 BHC/SL 97-130 BHC/SL 97-130 PEX-MICRO 97-130 8332 97-130 COMP RCD 97-130 COMP RCD ~R/BH 5928-8525 (c) 5050-8068 ~L (C) 3492-8065 ~Z~%L (C) 6800-8414 ~- BL (C) 3508-5658 ~BL (C) 3508-5658 ~BL (C) O-8068 (C) 3508-5642 (C) 3508-5642 ~4YLAR 6978-8386 · iL~-~BL (C) 3508-5617 ~/~BL (C) 3508-5617 {~/BL (C) 3508-5642 ,~CHLUM TDTP ,~J6890-7620 7/20/97 ~/;200-6650 8/17/97 08/22/97 1 03/17/98 1 03/17/98 2 03/17/98 1 03/17/98 1 03/17/98 1 03/17/98 1 03/17/98 1 03/17/98 1 03/17/98 1 03/17/98 1 03/17/98 1 03/17/98 1 03/17/98 1 03/31/98 1 03/31/98 lO-4O7 COMPLET O DATE DAILY WELL OPS R @(.fl3e)/~/ TO ~--i/~/~ Are dry ditch samples required? yes ~ And received? Was the well cored? yes ~,Analysis & description received? Are well tests required? yes ~ Received? ~~,~ Well is in compliance ~ Initial '' COMMENTS yes T D BOX -- Unocal Agricultural Products Diversified Business Group 909 West 9th Ave. Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 E-maih childersd @ unocal, com UNOCAL ) Debra Childers Geotech Assistant DATA TRANSMITTAL March 17, 1998 To: Laurie Taylor 3001 Porcupine Anchorage, AK 99501 Alaska Oil & Gas From' Debra Childers 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal Transmitting the following items: WELL NAME PRINT FILM SCALE DESCRIPTION RUN# DATE TBF A-3Ro3 1 1 5" Completion Record 1 7/20/97 TBF A-3RD3 ~ I ~, , 5" Completion Record 1 8/17/97 Unocal Agricultural Products Diversified Business Group 909 West 9th Ave. Anchorage, AK 99501 Tele: (907) 263-7869 Fax: (907) 263-7828 E-mail: childersd @.unocaL cc,~, , UNOCAL( Debra Childers Geotech Assistant DATA TRANSMITTAL March 17, 1998 To: Laurie Taylor :3001 PoFcupine AnchoFacje, AK 99501 Alaska Oil & Gas From' Debra Childers 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal Transmitting the following items: WELL NAME PRINT FILM SCALE DESCRIPTION RUN# DATE TBF A-3RD3 1 1 5' Borehole Compensated Sonic 1 5/3/97 TBF A-3RD3 1 1 2" Borehole Compensated Sonic 1 5/3/97 TBF A-3RD3 1 1 5' Cement Bond Variable 1 5/6/97 TBF A-3RD3 1 1 5' Completion Record 1 5/9/97 TBF A-3RD~ 1 1 5" Depth Determination/Whip Stock 1 4/13/97 TBF A-3RD3 1 1 5' Gage Ring/Junk Catcher 1 5/6/97 TBF A-3RD3 1 1 5' Platform Express Array Induction/GR 1 5/3/97 TBF A-3RD3 1 1 2" Platform Express Array Induction/GR 1 5/3/97 TBF A-3RD3 1 1 2" Platform Express Lithodensity/Neutron1 5/3/97 TBF A-3RD3 1 1 5" Platform Express Lithodensity/Neutron1 5/3/97 TBF A-3RD3 1 1 5" Platform Express Microlog 1 5/3/97 TBF A-3~d3 ~'~?~?.2~- Tape and Listing TBF A-3RD3 1 1 2" Thermal Decay Time Log 1 5/6/97 TBF A-3RD3 1 1 2" Thermal Decay Time Log 2 5/8/97 Ple,.ase acknowledqe receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. Received by'. ~ .'-~.. '-~'.~/(;Z~/ Date: --' STATE OF ALASKA ALASKA Oil_ AND GAS CONSERVATION L, OMMISSION 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) Unoin Oil Company of California (UNOCAL) Development: X 101' RT above MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519-6247 Service: Trading Bay State 4. Location of well at surface Monopod Pltf, Conductor #20 8. Well number 1616' FSL & 556' FEL Sec. 4, T9N, R13W, SM A-3RD3 At top of productive interval 9. Permit number/approval number 862' FNL & 874' FWL Sec. 3, T9N, R13W, SM 97-0130 / 397-134 At effective depth 10. APl number 155' FNL & 520' FWL Sec. 3, T9N, R13W, SM 50- 733-10057-03 At total depth 11. Field/Pool 109' FNL & 555' FWL Sec. 3, T9N, R13W, SM Trading Bay Field / Tyonek C & D 12. Present well condition summary Total depth: measured 8525' feet Plugs (measured) true vertical 7213' feet Effective depth: measured 8417' feet Junk (measured) true vertical 7121' feet Casing Length Size Cemented Measured depth True vertical depth Structural 182' 20" DRIVEN 227' 227' Conductor 368' 16" 500 sx 413' 413' Surface 1825' 13-3/8" 2480 sx 1870' 1739' Intermediate 3448' 9-5/8" 2708 sx 3493' 3039' Production 8465' 7" 1048 sx 8510' 7189' Liner Perforation depth: measured see attached true vertical see attached Tubing (size, grade, and measured depth) 2-7/8" 6.4# L-80 f/0 - 5506' '~ Packers and SSSV (type and measured depth) iGINAL HES "PHL" Pkr. @ 5328' 13. Stimulation or cement squeeze summary ~ i'! ib "~ ]~'~ 9 7 none Intervals treated (measured) none ...... Treatment description including volumes used and final pressure none 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mol Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 8/8/97 36 581 0 425 70 Subsequent to operation 8/19/97 78 60 56 610 70 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: ..~ii:(;~i c-'~/ c.~.,;.~ Title: /), ii,,,) /'L.L¢~(,,~:,c, Date: 8/29/1997 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Daily Report Of Well Opera,,ons MONOPOD A-3RD2 (WO) DAY 1 (7/20/97) SKID RIG TO A-3RD2 AT 1200 HRS 19 JULY 1997. INSTALL BPV AND N/D TREE. (WELL PREVIOUSLY KILLED) N/U BOP'S AND TEST TO 250/3000 PSI. BULLHEAD ADDITIONAL 42 BBLS DOWN TUBING. ENGAGE TUBING HANGAR AND PULL PACKER FREE WITH 133K OVERPULL. CIRCULATE BO-I-I'OMS UP AND MONITOR WELL. POOH WITH COMPLETION. LAY DOWN EXCESS TUBING GLM'S AND PACKER ASSEMBLY. R/U SCHLUMBERGER AND PERFORATE 7460- 7480', 7382-7422', 7160-7180', 7055-7075', AND 6978-7018' WITH 4-1/2" 5SPF CASING GUNS. M/U PACKER ASSEMBLY AND RUN 2-7/8" COMPLETION. DAY 2 (7/21/97) RUN 2-7/8 COMPLETION TUBING. M/U HANGAR AND CONTROL LINE. CONTINUE RIH. CIRCULATE TUBING VOLUME WITH HANGAR 5' OFF SEAT. R/U SLICKLINE, PULL DUMMY SSSV AND RIH WITH PACKER SETTING PLUG. SET PACKER WITH 3300 PSI. TEST ANNULUS TO 2000 PSi. RETRIEVE RHC PLUG. MAKE DUMMY GAGE RUN TO 8350'. (NO OBSTRUCTIONS) R/D SLICKLINE. SET BPV AND N/D BOP'S. DAY 3 (7/22/97) CONTINUE N/D BOP'S. N/U TREE AND TEST HANGAR SEALS TO 5000 PSI. SET TWO WAY CHECK VALVE AND TEST TREE TO 5000 PSI. RECOVER TWO WAY CHECK VALVE AND HAND WELL OVER TO PRODUCTION AT 0500 HRS 22 JULY. COMMENCE RIG DEACTIVATION OPERATIONS. DAY 4 & 5 (7/23-24/97) CONTINUE RIG DEACTIVATION PROCEDURES. OPERATIONS COMPLETE AT 2400 HRS ON 24 JULY 1997. RELEASE RIG: 7/24/97 @ 2400 HRS 8/15 PF - Perforate Tyonek W/2 1/8" Enerjet Guns, 6HPF, 0 Phase Zone Interval Feet C 5,420'-5,440' 20' C 5,490'-5,520' 30' C 5,555'-5,620' 65' C 5,795'-5,960' 165' C 6,050'-6,168' 118' C 6,203'-6,275' 72' C 6,285'-6,350' 65' C 6,382'-6,402' 20' C 6,528'-6,538' 10' TOTAL 565' AP 50-755-10057-05 Monopod Plat. form Conductor 20 TBS A-SRD5 Trading B_ay State Trading Bay Field RKB Elev. 101 FL MSL Tb.g Head Fig Depth 5g.02 Ft,. Mid-Perf Deviation 40.0 Degs. 42.6 - 227.0' 20" OD CSG J/ 42.6 - 415.0' 16" OD 75.00#/f[ J-55 CSG 415.0 - 413.0' SHOE 41.0 - 1870.0' 15.575" OD 61.00#/fi J-55 SURF CSO 1869.0 - 1870.0' SHOE z 41.0 - 5495.0' 9.625" OD 47.00#/fi N-80 INT CSG 5496.0 - 3496.0' SHOE Window 4/25/97z 41.0 - 8510.0' 7.00" OD 29.00#/ft L-80 PROD CSG 8417.0 - 8525.0' CEMENT PLUG 8508.7 - 8510.0' FLOATSHOE KB ELD/: 101' PBTD: 8417' TD: 8525' L L 59.2 - 5402.5' 2.875" OD 6.40#/f[ L-80 TBO 7/21/97 59.2 - 40.0' HANGER 526.0 - 528.5' 2.515" ID SSSV HES XXO 2529.7 - 2558.5' GASLIFT VALVE//1, McMurry SMO-1 GLM ,3501.0 - 3309.6' GASLIFT VALVE tt2, McMurry SMO-1 GLM 3951.1 - 5969.7' GASLIFT VALVE #3, McMurry SMO-1 OLM 4415.7 - 4424.3' GASLIFT VALVE #4, McMurry SMO-1 GLM 4877.1 - 4885.6' GASLIFT VALVE #5, McMurry SMO-1 GLM 5273.5 - 5281.9' OASLIFT VALVE//6, McMurry SMO-1 OLM · _ -,, wi '1 " ~,_ "XU" 5517 9 5~z2.., 2.~.3 iD qLF~/E HES Burg Sleeve 5328.4 - 5333.5' RETRV. PACKER HES "PHL" Pkr. 5369.0 - 5370.2' 2.3!~" tD LANDING NIPPLE HES 5402.5 - 5403.4' 2.441" ID REENTRY JOINT En[ry Guide Oil Well Redrilled 4/25/97 Lest Perf'd 8/15/97 APl 50-733-10057-03 Monopod Platform Conducf~or 20 8417.0 - 8525.0' CEMENT PLUG TBS A-SRD5 Trading B_ay St:ate Trading Hay Field KB ELEV: 101' PBTD: 8417' TD: 8525' RKB Elev. 101 FL MSL Tbg Head Fig Depth 39.02 FL Mid-Perf Devia[ion 40.0 Degs. 5402.5 - 5403.4' REENTRY JOINT Entry Guide 5420.0 - 5440.0' PERFS C, 8/15/97, 6HPF, 20', 2-1/8" Enerjet Guns, 0 Phase 5490.0 - 5520.0' PERFS C, 8/15/97, 6HPF, 30', 2-1/8" Enerjet Guns, 0 Phase 5555.0 - 5620.0' PERFS C, 8/15/97, 6HPF, 65', 2-1/8" Enerjet Guns, 0 Phase 5795.0 - 5960.0' PERFSC, 8/15/97, 6HPF, 165', 2-1/8" Enedet Guns, 0 Phase 6050.0 - 6168.0' PERFS C, 8/15/97, 6HPF, 118', 2-1/8" Enerjet Guns, 0 Phase 6205.0 - 6275.0' PERFSC, 8/15/97, 6HPF, 12', 2-1/8" Enedet Guns, 0 Phase 6285.0 - 6350.0' PERFSC, 8/15/97, 6HPF, 65', 2-1/8" Ene~et Guns, 0 Phase 6382.0 - 6402.0' PERFSC, 8/15/97, 6HPF, 20', 2-1/8" Enedet Guns, 0 Phase 6528.0 - 6558.0' PERFSC, 8/15/97, 6HPF, 10', 2-1/8" Enedet Guns, 0 Phase 6978.0 - 7018.0' PERFSC, 7/20/97, 5HPF, 6918.0 - 7011.0' PERFSC, 5/12/97, 6HPF, 7055.0 - 7075.0' PERFSC, 7/20/97, 5HPF, 7055.0 - 7077.0' PERFS C, 5/12/97, 6HPF, 7160.0 - 7180.0' PERFSC, 7/20/97, 5HPF, 7160.0 - 7182.0' PERFSC, 5/12/97, 6HPF, 7582.0 - 7422.0' PERFSC, 7/20/97, 5HPF, 7389.0 - 7422.0' PERFSC, 5/11/97, 6HPF, 7446.0 - 7479.0' PERFSC, 5/10/97, 6HPF, 7460.0 - 7480.0' PERFSC, 7/20/97, 5HPF, 7690.0 - 7156.0' PERFS C, 5/10/97, 6HPF, 7884.0 - 7917.0' PERFSC, 5/12/97, 6HPF, 8042.0 - 8075.0' PERFS C, 5/10/97, 6HPF, 8207.0 - 8240.0' PERFS C, 5/10/97, 6HPF, 8270.0 - 8305.0' PERFS C, 5/10/97, 6HPF, 8320.0 - 8386.0' PERFS C, 5/10/97, 6HPF, 40', 4-1/2" H. Densi~ Guns, 50 Phase 33', 2-1/8" Enedet Guns, 0 Phase 20', 4-1/2" H. Densi~ Guns, 50 Phase 22', 2-1/8" Ene~e[ Guns, 0 Phase 20', 4-1/2" H. Densi~ Guns, 30 Phase 22', 2-1/8" Ene~e[ Guns, 0 Phase 40', 4-1/2" H. Densi~ Guns, 50 Phase 35', 2-1/8" Ene~et Guns, 0 Phase 33', 2-1/8" Ene~et Guns, 0 Phase 20', 4-1/2" H. Densi~ Guns, 30 Phase 66', 2-1/8" Ene~et Guns, 0 Phase 53', 2-1/8" Ene~e[ Guns, 0 Phase 53', 2-1/8" Ene~et Guns, 0 Phase 55', 2-1/8" Enerje[ Guns, 0 Phase 53', 2-1/8" Enerjel: Guns, 0 Phase 66', 2-1/8" Enerjel: Guns, 0 Phase Oil Well Redrilled 4/25/97 Les[ Perf'd 8/15/97 AP 50-733-10057-03 Monopod Platform Conductor 20 TBS A-SRD3 Trading B_ay State Trading Hay Field RKB Elev. 101 FL MSL Tbg Head Fig Depth 59.02 Fl:. Mid--Perf Deviation 40.0 Degs. 42.6 - 227.0' 20" OD CSG _..J| 42.6 - 415.0' 16" OD 75.00#/fL J-55 CSG 415.0 - 415.0' SHOE 41.0 - 1870.0' 13.575" OD 61.00#/fl J-55 SURF CS6 1869.0 - 1870.0' SHOE 41.0 - 5495.0' 9,625" OD 47.00#/fl: N-80 IN!- CSG 3496.0 - 5496.0' SHOE Window 4/25/97 41.0 - 8510.0' 7.00" OD 29.00#/ft: L-80 PROD CSG 8417.0 - 8525.0' CEMENT PLUG 8508.7 - 8510.0' FLOATSHOE ,'./////~ PBTD: 8417' LL 41.5 - 42.3' HANGER 5M Cooper Hgr. 59.0 - 6900.5' 2.875" OD 8.40#/fL L-80 TBG 5/9/97 310.8 - 313.31 2.315" ID SSSV HES XXO 2380.7 - 2389.3' GASLIF-I- VALVE #1, McMurry SMO-1 GLM 5769.2 - 5778.1' GASLIFT VALVE//2, McMurry SMO-1 GLM 4484.0 - 4492.5' GASLIFT VALVE #3, McMurry SMO-1 GLM 5107.0 - 5115.6' GASLIFT VALVE//4, McMurry SMO-1 GLM 5566.0 - 5574.5' OASLIFT VALVE #5, McMurry SMO-1 OLM 6063.2 - 6071.8' GASLIFT VALVE//6, McMurry SMO-I GLM 6559.9 - 6568.5' GASLIFI- VALVE #7, McMurry SMO-1 GLM 6769.1 - 6777.7' GASLIFT VALVE #8, McMurry SMO-1 GLM 6815.9 - 6818.1' 2.513'~ ID SLEEVE HES "XU" 6824.7 - 6829.9' 2.441" ID RETRV. PACKER HES "FHL" Pkr. 6865.8 - 6867.0' 2.513" ID LANDING NIPPLE HE$ "X" 6899.1 - 6900.0' 2.441" ID REENTRY JOINT Entry Guide Oil Well Redrilled 4/25/97 Last Perf'd 5/11/97 AP 50-733-10057-03 Monopod PIc]f. form Conductor 20 8417.0 - 8525.0' CEMENT PLUG TBS A-SRD3 Trading B_ay Sf.c]te Trading Boy Field PBTD: 84! 7' RKB Elev. 101 FI:. MSL Tbg Head Fig Dept:h 39.02 Fl:. Mid-PerT Devidion 40.0 Degs. 39.0 - 6900.,3' 2.875" OD 8.40#/fi L-80 TBG 5/9/97 6865.8 - 6867.0' LANDING NIPPLE i-lES "X" 6899.1 - 6900.0' REENTRY JOINT En[ry Guide 6978.0 - 7011.0' PERFS C, 5/12/97, 6HPF, 55', 2-1/8" Enerjet Guns, 0 Phase 7055.0 - 7077.0' PERFSC, 5/12/97, 6HPF, 22', 2-1/8" Ene~et Guns, 0 Phase 7160.0 - 7182.0' PERFS C, 5/12/97, 6HPF, 22', 2-1/8" Enedet Guns, 0 Phase 7589.0 - 7422.0' PERFSC, 5/11/97, 6HPF, 35', 2-I/8" Enedet Guns, 0 Phase 7446.0 - 7479.0' PERFS C, 5/10/97, 6HPF, 53', 2-1/8" Enerjet Guns, 0 Phase 7690.0 - 7756.0' PERFS C, 5/10/97, 6HPF, 66', 2-1/8" Enerjet Guns, 0 Phase 7803.0 - 78.]6.0' PERFS C, 5/10/97, 6HPF, 53', 2-1/8" Enerjet Guns, 0 Phase 7884.0 - 7917.0' PERFS C, 5/12/97, 6HPF, 53', 2-1/8" Enerje[ Guns, 0 Phase 8042.0 - 8075.0' PERFS C, 5/10/97, 6HPF, 33', 2-I/8" Enede( Guns, 0 Phase 8207.0 - 8240.0' PERFS C, 5/10/97, 6HPF, 33', 2-1/8" Enerjet Guns, 0 Phase 8270.0 - 8305.0' PERFS 6, 5/10/97, 6HPF, ,~3', 2-1/8" Enerjet Guns, 0 Phase 8520.0 - 8386.0' PERFS C, 5/10/97, 6HPF, 66', 2-1/8" Enerjet Guns, 0 Phase Oil Well Redrilled 4/25/97 Lest Perf'd 5/11./97 ........ STATE OF ALASKA ' ALASK ,.)IL AND GAS CONSERVATIOr, COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: X GAS: SUSPENDED: ABANDONED: SERVICE: 2. Name of Operator 7. Permit Number UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 97-0130 3. Address 8. APl Number P.O. BOX 196247 ANCHORAGE, AK 99519-6247 50- 733-10057-03 4. Location of well at surface 1616' FSL& 556' FEL SEC 4, T9N, R13W SM At Top Producing Interval 6978' MD / 5902' TVD 862' FNL & 874' FWL SEC 3, T9N, R13W SM At Total Depth 8525' MD /7213' TVD 109' FNL& 555' FWL SEC 3, T9N, R13W SM 5. Elevation in feet (indicate KB, DF, etc.) 101' KB 6. Lease Designation and Serial No. ADL 18731 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 4/25/97 5/2/97 5/12/97 17. Total Depth (MD+TVD) 8525' MD/7213' TVD 18. Plug Back Depth (MD+TVD) I 19. Directional Survey 8417' MD/7121' TVD I Yes: x No: 9. Unit or Lease Name TRADING BAY STATE 10. Well Number A-3RD3 11. Field and Pool TRADING BAY FIELD TYONEK C&D 15. Water Depth, if offshore I 16. No. of Completions 62' feetMSLI 1 20. Depth where SSSV set 21. Thickness of Permafrost 312' feet MD 22. Type Electric or Other Logs Run GR/CNL/LDT/AIT/SONIC (3492'-5670') GR/CET/CBT (5050'-8068'); GR/CCLFFDT (3400'-8425'); Mudlog (3493'-8425'). 23. CASING, LINER AND CEMENTING RECORD SE'FI'lNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20' 45' 227' DRIVEN DRIVEN 0 16' 75# J-55 45' 413' 22' 500 SX 0 13-3/8' 61# J-55 45' 1870' 18-5/8' 2480 SX 0 9-5/8' 47# N-80 45' 3493' KO P 12-1/4" 2708 SX 0 8510' 8-1/2' 1048 SX 0 7" 29# L-80 45' 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) See Attachements 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8'. 6.4#, L-80 6901' 6826' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 5/10/1997 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 5/18/97 12 TEST PERIOD => 38 31 0 104 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 85 935 24-HOUR RATE => 76 63 0 28 28. CORE DATA Brief description of litho!ogy, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate --" STATE OF ALASKA l ALASKA OIL AND GAS CONSERVATION CuMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: X Variance: Perforate: X Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) UNION OIL COMPANY OF CALIFORNIA (UNOCAL) Development: X KB 101 feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. BOX 196247 ANCHORAGE, AK 99519-6247 Service: TRADING BAY STATE 4. Location of well at surface 8. Well number 1616' FSL & 556' FEL SEC 4, T9N, R13W SM A-3RD3 At top of productive interval 9. Permit number 862' FNL & 874' FWL SEC 3, T9N, R13W SM 97-0130 At effective depth 10. APl number 155' FNL & 520' FWL SEC 3, T9N, R13W SM 50- 733-10057-03 At total depth 11. Field/Pool 109' FNL & 555' FWL SEC 3, T9N, R13W SM TRADING BAY FIELD/TYONEK C & D 12. Present well condition summary Total depth: measured 8525 feet Plugs (measured) true vertical 7213 feet Effective depth: measured 8417 feet Junk (measured) None true vertical 7121 feet Casing Length Size Cemented Measured depth True vertical depth Structural Existing 182' 20" DRIVEN 227' 227' Conductor Existing 368' 16" 500 sx 413' 413' Surface Existing 1825' 13-3/8" 2480 sx 1870' 1739' Intermediate Window 3448' 9-5/8" 2708 sx 3493' 3039' Production 8465' 8-1/2" 1048 sx 8510' 7189' Liner Perforation depth: measured Please See Attachments,,, _nR GI , AL------ true verticalJ U L 3 t 1997 Tubing (size, grade, and measured depth) Please see attached schematic. ~]-~._~_'~_ .0il ~& f~as C0r~s, C0rr~i~iss~o' "'-~ach'0ra§el .'-' Packers and SSSV (type and measured depth) Please see attached schematic. 13. Attachements Description summary of proposal: X Detailed operations program: X BOP sketch: X 14. Estimated date for commencing operation 15. Status of well classification as: 7/19/97 contact: Kriss Wegemer @ 263-7655 16. If proposal well verbally approved: Oil: X Gas: Suspended: , Jack Hartz 7/18/1997 Name of approver Date approved Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: ]pC_~ ~ ~ '~\ ~-,. Title: Drilling Manager Date: 7/20/1997 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity.~ BOP Test t~ Location clearance Mechanical Integrity Test Subsequent form required 10- ..,,,~j,,~'~at Signed By Oavid W. Johnston Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Description of Proposal Workover-- Well A-3RD3 Monopod Platform Trading Bay Field Purpose of Proposed Workover Well A-3RD3, redrilled to the C-Zone Subthrust in 5/97, is currently producing at a marginal rate of approximately 50 BOPD, 0 BWPD. In an effort to increase production from the well, a workover is recommended to move the production packer up hole to access additional productive interval. The workover is expected to result in an incremental increase in production of approximately 100 BOPD. Plan: The well will be killed with work over fluid (8.6 ppg filtered inlet water with 3 % KCL). Tubing and packer will be pulled and reset up hole such that the end of tubing is at +/- 5400' MD. In addition to reperforating some of the existing interval, new perforations will be added using a 2-1/8" strip gun, 6 SPF and 0 phase. The proposed perforating is as detailed on the Application for Sundry. Benefit: The workover of A-3RD3 will allow access to additional Subthrust C-Zone and increase production by an estimated 100 BOPD. Redrilled and completed in the Subthrust C-Zone in 5/97, A-3RD3 is a Iow rate producer with current production of approximately 50 BOPD, 0 BWPD. A down hole build up run in 7/97, although incomplete due to an apparent leak around the shut-in tool, indicated that the reason for the poor response from the well is tight rock. Permeability is less than 0.5 md and the skin is less than +1. The Iow productivity is inferred to be primarily due to the mechanical degradation of steeply dipping beds, and secondarily to proximity to the Trading Bay Fault. Reservoir pressure is roughly estimated to be +/- 2500 psi, which is near original pressure. Since rate and recovery improvement is limited in the current completion, it is recommended to workover the well and reset the packer up hole to access additional intervals. Evidence from the gamma ray and porosity measurements on the TDT log (open hole logging unsuccessful below 5642'), indicate an increase in potential production. AP 50-753-10057-03 Monopod Plof. form Conductor 20 54-20.0 - 5440.0' PERFS Proposed C, 1997, 6HPF, 20', 4-1/2" Csg. Guns, 0 Phase 54-90.0 - 5520.0' PERIS Proposed C, 1997, 6HPF, 30', 4-1/2" Csg. Guns, 0 Phase 5555.0 - 5620.0' PERFS Proposed C, 1997, 6HPF, 65', 4-1/28" Csg. Guns, 0 Phase 5795.0 - 5960,0' PERIS Proposed C, 1997, 6HPF, 165', 4-1/28" Csg. Guns, 0 Phase 6050.0 - 6168.0' PERIS Proposed C, 1997, 6HPF, 118', 4-1/28" Csg. Guns, 0 Phase 6205.0 - 6275.0' PERIS Proposed C, 1997, 6HPF, 72', 4-1/28" Csg. Guns, 0 Phase 6285.0 - 6,5,50.0' PERIS Proposed C, 1997, 6HPF, 65', 4-1/28" Csg. Guns, 0 Phase 6582.0 - 6402.0' PERIS Proposed C, 1997, 6HPF, 20', 4-1/28" Csg. Guns, 0 Phase 6528.0 - 6538.0' PERIS Proposed C, lg97, 6HPF, 10', 4-1/28" Csg. Guns, 0 Phase 6978.0 - 7018.0' PERIS Proposed C, 1997, 6HPF, 40', 2-1/8" Enerjet Guns, 0 Phase 7055.0 - 7075.0' PERIS Proposed C, 1997, 6HPF, 20', 2-1/8" Enerjet Guns, 0 Phase 7160.0 - 7180.0' PERFS Proposed C, 1997, 6HPF, 20', 2-1/8" Enerje[ Guns, 0 Phase 7382.0 - 7422.0' PERIS Proposed C, 1997, 6HPF, 40', 2-1/8" Enerjet Guns, 0 Phase 7460.0 - 7480.0' PERIS Proposed C, 1997, 6HPF, 20', 2-1/8" Enerjet Guns, 0 Phase 8417.0 - 8525.0' C~N¥ PLUG TBS A-SRD5 Tradin9 B_ay Stab Trodin9 Bay Fie d PBTD: 84-17' RKB Elev. 101 Fl:. MSL Mid-- Perf Deviotion ~-0.0 Degs. 5107.0 - 5115.6' GASLIFT VALVE #4, McMurry SMO-1 GLM 5566.0 - 5574.5' C¢,SUFT VALVE #5, McMurTy SMO-1 GLM 39.0 - 6900.3' 2.875" 00 8.40t/ft L-80 TBG 5/9/97 6065.2 - 6071.8' GASLIF[ VALVE #6, McMurry SMO-1 GLM 6559.9 - 6568.5' C, ASLIFT VALVE #7, McUurry SMO-1 GLM 6899.1 - 6900.0' 2.441" ID RENTRY JOINT Entry Guide 6769.1 - 6777.7' GASLIFT VALVE #8, McMurry SMO-1 GLM 6813.9 - 6818.!' 2.313" lO SLEBtE HES "XU" 6824.7 - 6829.9' 2.441" ID REI'RV. PACKER HE'S "Fill_" Pkr. 6978.0 - 7011.0' PERFS C, 5/12/97, 6HPF, 53', 2-1/8" Enerjet Guns, 0 Phase 7055.0 - 7077.0' PERIS C, 5/12/97, 6HPF, 22', 2-1/8" Enerjet Guns, 0 Phase 6865.8 - 6867.0: 2.313" ID LANOING NIPPLE HES "X" 7160.0 - 7182.0' PERFS C, 5/12/97, 6HPF, 22', 2-1/8" Enerjet Guns, 0 Phase 7589.0 - 7422.0' PERF5 C, 5/11/97, 6HPF, 53', 2-1/8" Enerjet Guns, 0 Phase 7446.0 - 7479.0' PERIS C, 5/10/97, 6HPF', 53', 2-1/8" Enerjet Guns, 0 Phase 7690.0 - 7756.0' PERPS C, 5/10/97, 6HPF, 66', 2-1/8" Enerjet Guns, 0 Phase 7803.0 - 7836.0' PERIS C, 5/10/97, 6HPF, 53', 2-1/8" Enerjet Guns, 0 Phase 7884.0 - 7917.0' PERFS C, 5/12/97, 6HPF, 53', 2-1/8" Enerjet Guns, 0 Phase 8042.0 - 8075.0' PERPS C, 5/10/97, 6HPF, 53', 2-1/8" Enerjet Guns, 0 Phase 8207.0 - 8240.0' PERIS C, 5/10/97, 6HPF, 53', 2-1/8" Enerjet Guns, 0 Phase 8270.0 - 8,.t05.0' PERIS C, 5/10/97, 6HPF, 53', 2-1/8" Enerjet Guns, 0 Phase 8320.0 - 8586.0' PEP, IS C, 5/10/97, 6HPF, 66', 2-1/8" Enerje[ Guns, 0 Phase Oil Well Redrilled 4/25/97 Lost Perf'd 5/11/97 Unocal Alaska Resources Monopod Platform Well: A-3rd3 Preliminary Procedure for 1997 Rig Workover Program UNOCAL No. Preliminary Procedure Time CUM CUM Estimate Time Time (Hours) (Hours) (Days) 1 Skid overA-9RD 4.0 4 0.2 2 Kill Well with 8.6 ppg FIW W/3% KCL, Estimated Resv. Pr. 2500 psi 2.0 6 0.3 3 Test Wellhead packoffs 4.0 10 0.4 4 Pull SSSV 4.0 14 0.6 5 Check H2S detection equipment 1.0 15 0.6 6 Set BPV, N/D tree 4.0 19 0.8 7 N/U BOP, change BPV for 2WC, test BOP's 10.0 29 1.2 8 H2Sdrill 1.0 30 1.3 9 Pull packer free, Circulate well clean 6.0 36 1.5 10 POH, stand back +/- 6800' tbg, lay GLM's on deck 14.0 50 2.1 11 P/U new packer, M/U & RIH w/new gas lift completion 12.0 62 2.6 12 Land tubing hanger, set and test packer 3.0 65 2.7 13 Set BPV, N/D BOPE 5.0 70 2.9 14 N/U and test tree 4.0 74 3.1 15 I Rig down and cold stack rig 48.0 122 5.1 16 !Release rig 0.0 122. 5.1 Subtotal (Days) 5.1 Loss/Trble Time (11%) 0.6 Total Project Days 5.6 JUL Procedure for State.xls Page I of 1 7/30/97 MONOPOD A-3RD3 BOP SCHEMATIC 5000 PSI WORKING PRESSURE ANNULAR BOP 13-5/8" 5000 PSI PIPE RAMS 13-5/8" 5000 PSI ,, CHOKE LINE TO MONOPOD CHOKE MANIFOLD HCR 5000 PSI PIPE RAMS 13-5/8" 5000 PSI MANUAL 5M VALVE MUD CROSS BLIND RAMS 13-5/8" 5000 PSI RISER 13-5/8" 5000 PSI MANUAL 5M GATE F OM II MUD PUMP& [ I CEMENT UNIT U ,, KILL LINE DSA 13-5/8" 5M TO 11" 5M CIW 13-5/8" 3M X 11" 5M DCB SPOOL .ti -~ ~ ;¢,~1 ?,! MONOPOL _ LATFORM WELL # A-3RD3 ACTUAL COMPLETION 5/12/97 KB = 101' RKB from MSL III CASING AND PLUG DETAIL SIZE WT GRADE CONN TOP BOTTOM I) 20" 0 II) 16" 75 J-55 0 HI) 13-3/8" 61 J-55 0 IV) 9-5/8" 47 N-80 0 V) 7" 29 L-80 0 227' 413' 1870' 3500' (KOP) 8510' 12 V PBTD=8417' TD -- 8525' MAX HOLE ANGLE = 40° W:\WORD60LMONOPOD\WBD Actual, A3-RD3 TUBING DETAIL 1) 2) 3) 4) 5) 6) 7) 8) 9) 10) 11) 12) 13) 14) 2-7/8" 6.4# N-80 BTC HES 2.313 .... XXO" SVLN ~ 311' McMurry SMO-1 GLM ~ 2381' W/1" VALVE McMurry SMO-1 GLM ~ 3770' W/1" VALVE McMurry SMO-1 GLM ~ 4484' W/1" VALVE McMurry SMO-1 GLM ~ 5107' W/1" VALVE McMurry SMO-1 GLM ~ 5566' W/1" VALVE McMurry SMO-1 GLM ~ 6063' W/1" VALVE McMurry SMO-1 GLM ~ 6560' W/1" VALVE McMurry SMO-1 GLM ~ 6769' W/1" VALVE HES "XU" 2.313" SLDING SLEEVE ~ 6814' HES 7 ....PHL" PACKER ~ 6825' 2.313 .... X" LANDING NIPPLE ~ 6866' WLRG ~ 6900' PERFORATION DATA MD MD TVD TVD TOP BTM TOP BTM 6978 7011 7055 7077 7160 7182 7389 7395 7395 7422 7446 7479 7690 7723 7723 7756 7803 7836 7884 7917 8042 8075 8207 8240 8270 8303 8320 8353 8356 8375 8375 8386 5901 5929 5965 5983 6050 6069 6240 6245 6245 6267 6287 6315 6495 6524 6524 6552 6593 6622 6663 6692 6798 6826 6938 6965 6990 7018 7032 7059 7061 7077 7077 7086 DRAWN BY: PAR 7/18/97 ---- STATE OF ALASKA ALASKA C,-AND GAS CONSERVATION ,.,OMMISSiON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: X .SAS: SUSPENDED: ABANDONED: SERVICE: 2. Name of Opera::: 7. Permit Number UNION OIL C3MPANY OF CALIFORNIA fUNOCAL! 97-0130 3. Address 8. APl Number P.O. BOX 196247 ANCHORAGE. AK 99519-6247 50- 733-10057-03 4. Location of weii at surface 1616' FSL & 553' FEL SEC 4, T9N, R13W SM At Top Producing ::',terval 6978' MD / 5902' TVD 862' FNL & 874' FWL SEC 3, T9N, R13W SM At Total Depth 8525' MD / 7213' TVD 109' FNL & 555' FWL SEC 3, T9N. R13W SM 5. Elevation in feet ;indicate KB, DF, etc.) 101' KB 9. Unit or Lease Name TRADING BAY STATE 10. Well Number A-3RD3 11. Field and Pool TRADING BAY FIELD TYONEK C&D 12. Date Spuddea 13. Date T.D. Reached 14. Date Comp., Sus:_ or Aband. 15. Water Depth, if offshore [ 16. No. of Cc.-,,Dietions 4/25/97 5/2/97 5/12/97 62' feet MSL] 1 17. Total Depth (MD?'T-VD)8525, MD / 72: 3' TVD 18. Plug Back Depth (MD+TVD)8417, MD/7121'TVD 119' Directi°n~ Survey {2°' Depth where sssv setYes: x ',:.: 312' footMD J 21. Thickness. of ~-=_rmafrost 22. Type Electric c: Other Logs Run GR/CNL/LDT.'-';T/SONIC f3492'-5670') GR/CET/CBT (5050'-8068'); GR/CC'._TDT (3400'-8425'); Mudlog (3493'-8425'). 23. CASING. LINER AND C=MENTING RECORD SE'I-I'ING DEPTH MD CASING SIZE ,',q'. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUN- PULLED 20" 45' 227' DRIVEN DRIVEN ; 16' 75# J-55 45' 413' 22" 500 SX : 13-3/8" 61 # J-55 45' 1870' 18-5/8" 2480 SX : 9-5/8" 47# N-80 45' 3493' KOP 12-1/4' 2708 SX ,3 7" 29# L-80 45' 8510' 8-1/2" 1048 SX : 25. TUBING RECORD 24. Perforations o,'en to Production (MD+TVD of Top and Bottom and interval, size ar-.a number) See Attacnements SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8". 6.4#. L-80 6901' 6826' 26. ACID. FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATE;.!AL USED 27. PRODUCT:3 N TEST Date First Produc,c:n Method of Operation (Flowing, gas ~tff. etc.) 5/10/1997 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL I 3, AS-MCF WATER-BBL CHOKE SIZE GAS-OIL RAT:O 5/18/97 12 TEST PERIOD => 38 I 31 0 104 Flow Tubing 3~sing Pressure CALCULATED OIL-BBL i 3, AS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 85 935 24-HOUR RATE --> 76 I 63 0 28 28. CORE ,L' .'-,TA Brief description cf :'.hology, porosity, fractures, apparent dips and presence of o:: ;as or water. Submit core chips. Form 10-4-$7 Rev. 7-1-83 OR.IGINAL CONTINUED ON F--_VERSE SIDE JUL 22 1997 Submit in au::~cate '29. 30. GEOLOGIC MARKERS FORMATION TESTS · NAME Include interval tested, pressure data, all fluids recovered and gravity, ~EAS. DEPTH TRUE VERT. DEPTH GOR, and lime of each phase. C - Zone 3,493' 3,039' KOP No Tests Trading Bay Fault 5,702' 4,858' Into C - Zone below fault. C - Zone Lower Sands 6,965' 5,892' Tested selected sands between 6,975 - 8,390' ( 440' total perforated interval ). 70 BOPD, 0% cut, 28 deg. APl. !~.---,.~ ¢_ .'..a ?';' ? -'¢ - ,. 31. LIST OF A'FI'ACHMENTS PERFORATION DATA SHEET, ABANDONDED WELL SCHEMATIC, SUMMARY REPORT OF OPERATIONS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injeclion, observation, injection for in-situ combustion. Item 5: Indicate which elevalion is used as reference (where not otherwise shown) for depth measurements given in other space on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Rowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 1997 4/24-30/97 5/1-8/97 MONOPOD PLATFORM WELL HISTORY SUMMARY WELL A-3RD3 HISTORY SUMMARY 9-5/8" KOP @ 3492' MD. DRILL 5-1/2" HOLE F/7,246' TO 7,261' POH TO 6.763 W/O DIFFICULTIES, PULLED 30K OVER ~ 6,919'. START ROTATING & CIRC @ 6,763', ROTATE FREE BUT PACKING OFF. RIH ROTATING AND %~. ATTEMPTING TO CIRC. SPOTTED 350 SX BALANCED CEMENT KICK OFF PLUG FROM 6,545' TO 6,000'. CiRC CLE,~N AFl'ER CMT JOB. POH AND LAY DN 2-7/8" STINGER. MAKE UP .MOTOR ASSY, BHA #6. DRILL STRINGER @ 561~9' AND FIRM CMT F/5,639 TO 5,80'. DRILL 8-1/2" HOLE F/6889' TO 7074'. RIH WfMOTOR ASSBY, BHA #7. TST MOTOR & MWD. DRILL 8-1/2" HOLE F/7731' TO 7976'. ROTARY DRILLED 8-1/2" FROM 7731'-7978'. CIRC BTM UP FOR TRIP @ 7978'. POOH. POH W/BHA #7, LAYED DOWN INTEQ MWD, COLLAR, AND MUD MOTOR. RIH W/BIT #8, BHA #8. STRAIGHT MOTOR ASSBY TO 3400'. CONT RIH W/BIT AND BHA #8. DRILL 8-1/2" HOLE F/7978' WITH STRAIGHT MOROT ASSBY. DRILL 8-1/2" HOLE @ 8225' @ 2400 HRS. DRILLED 8-l/2" HOLE F/8225'-8525' (TD). CCH FOR LOGS. POOH. RIH W/GR/CNL/LDT/AIT/SONIC. SET DOWN @ 5670'. LOG OUT F/5670'-3492'. POOH & SHORTEN TOOLS. RIH & SET DOWN @ 5670'. POOH RD LOGGING L.'?,'IT. RIH W/CLEANOUT BHA & CLEANOUT TO 8525'. CCH FOR CASING. POOH. CH,aZqGE RAMS IN BOP TO 7". RIH W/7" 29# CASING TO 8510'. CCH FOR CEMENT. CEMENT 7" CASING @ 8510' W/ 183 BBLS LEAD @ 12.9 PPG F/B 111 BBLS TAIL @ 15.8 PPG. LOST RETURNS AFTER 178 BBLS OF DISPALCEMENT PU%IPED. CIP @ 0400 HRS RIH W/ TDT/GR/CCL & TAGGED BOTTOM @ 8068'. LOG UP W/TDT/GR/CCL F/8068'- 3492'. RIH W/CET/CBT/GR/CCL & LOG F/8068'-5050'. RD WIRELINE RIH PU 3-1/2".DRILL PIPE. TAG CEMENT @ 8045'. WASH DOWN TO 8200'. DRILL FIRM' CEMENT F/8200'-8417'. CiRC HOLE W/3% KCL. POOH LD 3-I/2" DRILL PIPE. RU WIRELINE. RUN TDT,'GR/CCL F/8417'-6800'. POOH. RIH W/2-7/8" GLM COMPLETION. END OF TUBING ~ 6901', PACKER @ 6831', SVLN @ 315'. LAND HANGER, DROP BALL & SET PACKER. SHEAR BALL OFF SEAT W/3500 PSI. TEST TUBING & PACKER TO 2500 PSI. OK. SET TWO WAY CHECK, ND BOP. NU TREE. 5/9-12/97 5/12 NU & TEST TREE. RU SLICKLI*'E & RECOVER DUMMY SAFETY VALVE. RIH W/SLICKLINE & CLEAR END OF TUBING. RD SLICKLINE. GAS LIFTING WELL FOR UNDERBALANCE. PERFORATE WELL W/2-1/8" 6 SPF 0° PHASED STRIP GUNS AS FOLLOWS: 8356'-8386', 8320'-8353', 8270'-8303', 8207'-8240', 8042'i8075', 7803'-7836', 7723'-7756', 7690'-7723', 7446'-7479', 7389'-7395'. PERFORATING W/2-1/8" 6 SPF ©: PHASED STRIP GUNS AS FOLLOWS: 7395' 7422', 7884'-7917', 7160'-7182', 7555'-7077', 6978'-7011'. RD WIRELINE. FLOW WELL TO PRODUCTION TO CLEAN UP. SKID RIG TO A-27RD. RIG RELEASED @ 1800 HRS 5/12/97. COMPLETED AS A SINGLE STRING WELL WAS WELL. PERFORATION DATA SHEET ADL 18731 MONOPOD A- 3RD3 Perforated C Date Zone W/2-1/8" Enerjet Guns, 6HPF, 0 Phase. Zone Interval MD Interval TVD - 7,011' - 7,077' - 7,182 ' - 7,422 ' - 7,479' - 7,756' - 7,836' - 7,917' - 8,075' - 8,240' - 8,303' - 8,386' 5/12/97 C Zone 6,978' 5/12/97 C Zone 7,055' 5/12/97 C Zone 7,160' 5/11/97 C Zone 7,389' 5/10/97 C Zone 7,446' 5/10/97 C Zone 7,690' 5/10/97 C Zone 7,803' 5/10/97 C Zone 7,884' 5/10/97 C Zone 8,042' 5/10/97 C Zone 8,207' 5/10/97 C Zone 8,270' 5/10/97 C Zone 8,320' 5,901 5,965 6,050 6,240 6,287 6,495 6,593 6,663 6,798 6,938' 6,990' 7,032' 5,929' 5,983' 6,069' 6,267' 6,315' 6,552' 6,622' 6,692' 6,826' 6,965' 7,018' 7,086' UNOCA~. MONOPOD Platform A3Rd3 slot #20 Trading Bay Field TBU, Cook Inlet, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref = PMSS <5982 - 8525~> Our ref = svy5566 License = Date printed : 21-Jul-97 Date created : 27=Apr-97 Last revised : 21-Jul-97 Field is centred on n60 53 32.779,w151 34 32.077 Structure is centred on n60 53 32.779,w151 34 32.077 Slot location is n60 53 48.692,w151 34 43.316 Slot Grid coordinates are N 2523129.377, E 218880.709 Slot local coordinates are 1616.00 N 556.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North O ISlNAL UNOCAL MONOPOD Plat form,A3Rd3 Trading Bay Field,TBU, Cook Inlet, Alaska Measured Inclin. Azimuth True Vert R E C T A N G Depth Degrees Degrees Depth C 0 0 R D I N SURVEY LISTING Page 1 Your ref : PMSS <5982 - 8525'> Last revised : 21-Jul-97 U L A R Dogleg Vert A T E S Deg/100ft Sect 5982.00 37.50 19.80 5082.34 2248.33 N 1436.05 E 0.70 2650.73 6023.00 35.40 16.70 5115.32 2271.45 N 1443.69 E 6.81 267%.85 6053.00 35.00 15.88 5139.84 2288.04 N 1448.54 E 2.06 2691.89 6103.00 34.20 13.95 5181.00 2315.48 N 1455.85 E 2.71 2719.75 6133.00 33.90 10.73 5205.85 2331.88 N 1459.44 E 6.09 2736.06 6165.00 34.30 9.17 5232.35 2349.55 N 1462.54 E 3.01 2753.29 6195.00 34.10 6.27 5257.17 2366.25 N 1464.81 E 5.47 2769.29 6226.00 33.90 2.72 5282.87 2383.53 N 1466.17 E 6.44 2785.40 6259.00 33.80 1.54 5310.28 2401.90 N 1466.85 E 2.01 2802.20 6305.00 33.90 1.13 5348.48 2427.51 N 1467,45 E 0.54 2825.47 6351.00 34.10 2.42 5386.62 2453.22 N 1468.24 E 1.63 2848.92 6381.00 34.10 2.45 5411.46 2470.03 N 1468.96 E 0.06 2864.32 6411.00 34.00 2.42 5436.31 2486.81 N 1469.67 E 0.34 2879.71 6444.00 33.90 3.55 5463.69 2505.21 N 1470.63 E 1.94 2896.66 6489.00 33.60 4.26 5501.10 2530.15 N 1472.33 E 1.10 2919.81 6537.00 33.80 3.51 5541.04 2556.73 N 1474.14 E 0.96 2944.47 6582.00 33.80 0.67 5578.44 2581.74 N 1475.05 E 3.51 2967.34 6612.00 34.30 358.51 5603.29 2598.53 N 1474.93 E 4.36 2982.37 6654.00 34.50 357.70 5637.95 2622.25 N 1474.14 E 1.19 3003.32 6723.00 35.60 353.55 5694.44 2661.73 N 1471.10 E 3.80 3037.45 6816.00 36.40 345.37 576-9.72 2715.36 N 1461.09 E 5.24 3081.22 6862.00 35.40 341.04 5806.99 2741.17 N 1453.31 E 5.93 3100.98 6909.00 35.10 337.20 5845.38 2766.51 N 1443.65 E 4.76 3119.49 6955.00 34.80 335.48 5883.08 2790.64 N 1433,07 E 2.24 3136.52 7004.00 34.80 331.40 5923.32 2815.65 N 1420.58 E 4.75 3153.48 7033.00 35.00 328.09 5947.11 2829.97 N 1412.22 E 6.57 3162.68 7098.00 35.40 326.76 6000.23 2861.54 N 1392.05 E 1.33 3182.16 7149.00 34.90 328.83 6041.93 2886.38 N 1376.40 E 2.53 3197.59 7192.00 35.40 329.80 6077.09 2907.67 N 1363.76 E 1.74 3211.16 7232.00 35.10 332.68 6109.75 2927.90 N 1352.66 E 4.22 3224.45 7286.00 34.80 333.76 6154.02 2955.52 N 1338.72 E 1.27 3243.13 7331.00 33.10 336.49 6191.35 2978.31 N 1328.14 E 5.07 3258.94 7379.00 33.40 336.07 6231.49 3002.40 N 1317.55 E 0.79 3275.93 7425.00 33.60 335.62 6269.85 3025.57 N 1307.16 E 0.69 3292.17 7472.00 33.60 337.17 6308.99 3049.40 N 1296.75 E 1.82 3309.00 7518.00 31.20 338.57 6347.83 3072.22 N 1287.45 E 5.47 3325.41 7566.00 30.80 338.76 6388.98 3095.25 N 1278.46 E 0.86 3342.14 7610.00 31.00 338.15 6426.73 3116.27 N 1270.16 E 0.84 3357.37 7658.00 31.20 338.86 6467.83 3139.34 N 1261.08 E 0.87 3374.10 7701.00 30.10 340.57 6504.82 3159.90 N 1253.47 E 3.26 3389.22 7752.00 29.80 341.99 6549.01 3184.01 N 1245.30 E 1.51 3407.28 7800.00 30.00 341.74 6590.63 3206.75 N 1237.85 E 0.49 3424.43 7846.00 30.40 341.83 6630.38 3228.73 N 1230.62 E 0.88 3440.99 7892.00 30.50 339.89 6670.04 3250.75 N 1222.98 E 2.15 3457.41 7939.00 30.90 339.77 6710.45 3273.27 N 1214.70 E 0.86 3474.00 8525.00 30.90 339.77 7213.28 3555.64 N 1110.64 E 0.00 3681.88 Projected Data - NO SURVEY Coordinates from slot #20 and TVD from wellhead (101.00 Ft above mean sea level). E~ Bottom hole distance is 3725.0? on azimuth 17.35 degrees from wellhead. Vertical section is from wellhead on azimuth 26.08 degrees. .,] (ii,.~.~ ~,'- !,~?~ Calculation uses the minimum curvature method. -- UNOCAL MONOPOD Platform, A3Rd3 Trading Bay Field, TBU, Cook Inlet, Alaska SURVEY LISTING Page 2 Your ref : PMSS <5982 - 8525'> Last revised : 21-Jul-97 Comments in we11path MD TVD Rectangular Coords. Comment ........................................................................................................... 8525.00 7213.28 3555.64 N 1110.64 E Projected Data - NO SURVEY Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised A3Rd#3 25-Apr-97 5737.00 2719.31N 1442.20E 25-Apr-97 2800 ] 3000 5200 3400 3600 5800 4000 4200 4400 ~ 4600 _C: 4800 5000 '~ 5200 ~ 54O0 I 5600 V 58OO 6000 q 6200 6400 66O0 6800 7000- 7200 7400 UNOCAL Structure : MONOPOD Platform Well : A:SRd3 Field : Trading Bay Field Location : TBU, Cook Inlet, Alaska UNOCAL ) East (feet) -> 800 1000 1200 1400 1600 1800 , / ,P / ? I I I f 3600 3400 3200 3000 28O0 2600 2400 O 2200 2000 ,--I- 1800 1600 1400 1200 1000 800 Created by finch } Dote plotted : 15-May-97 Plot Reference ~s A-5 Rd #2 Version #5. Coordinates ~=re in feet reference slat #20.[ True Vertical Dep~rence wellhead.[ I I I I I t I I I I I I I I II I II I I I I I I I I I I 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 5800 Vertical Section (feet) -> Azimuth 26.08 with reference 0.00 S, 0.00 E from slot //20 TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 17. 1997 Dale Haines Drilling Manager UNOCAL P O Box 196247 Anchorage, AK 99519-6247 Re: Trading Bay Unit A-3RD3 UNOCAL Permit No. 97-130 Surf Loc 1616'FSL & 556'FEL of Sec. 4. T9N. R13W. SM Btmhole Loc 109'FNL & 555'FWL of Sec. 3. T9N. R13W. SM Dear ,.Mr. Haines: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you. from obtaining additional permits required bv law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the sUrface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given 15y contacting the Commission at 279-1433. S' Chairman~ ~ BY ORDER OF THE COMMISSION dlf/encl Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl - STATE OF ALASKA - ALASKA OiL AND GAS CONSERVATION C, MMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type.of work Drill: Redrill: x I lb. Type of well Exploratory: Stratigraphic Test: Development Oil: x Re-Entry: Deepen:I Service: Developement Gas: Single Zone: Multiple Zone: 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Union Oil Company of California (UNOCAL) KB 101 feet TRADING BAY FI ELD/ 3. Address 6. Property Designation TYONEK C & D P.O. Box 196247 Anchorage, AK 99519-6247 ADL 18731 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 1616' FSL & 556' FEL OF SEC. 4, T9N, R13W, SM TRADING BAY STATE AK STATEWIDE OIL & GAS BOND At top of productive interval 8. Well number Number U62-9269 A-3RD3 At total depth 9. Approximate spud date Amount $200,000 109' FNL & 555' FWL OF SEC. 3, T9N, R13W, SM 4/25/97 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD and TVD) property line A-18 109 feet 798' @ 5900' TVD feet 3840 8525' MD / 7213' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure(see 20 AAC 25.035 (e)(2)) Kickoff depth: 3493 feet Maximum hole angle: 40 Maximum surface 405 psig At total depth (TVD) 2839 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) EXISTING 20" 182' 45' 45' 227' 227' DRIVEN EXISTING 16" 75 J-55 BTC 368' 45' 45' 413' 413' 500 SX EXISTING 13-3/8" 61 J-55 BTC 1825' 45' 45' 1870' 1739' 2480 SX EXISTING 9-5/8" 47 N-80 BTC 3448' 45' 45' 3493' KOP 3039' _~708 SX 8-1/2" 7" 29 L-80 BTC 8466' 45' 45' 8510' 7213' 1048 SX 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 7261' feet Plugs (measured) CMT PLUG 6268' - 6545' ORIGINAL Effective depth: measured 7261' feet Junk (measured) true vertical 7072' feet Casing Length Size Cemented Measured depth True vertical depth Structural 182' 20" DRIVEN 227' RE~ V D Surface 1825' 13-3/8" 2480 SX 1870' 1739' 346r i99 IntermediateWindow 3460' 9-5/8" 2708 SX 3505' '.-J U b 7072, Production open Hcle 3756' 8-1/2" 7261' Liner Alaska OiJ & Gas Cons, Cornmissio~l Perforation depth: measured N/A , Ar~ch0rage true vertical N/A Please see A-3RD2 10-401 for additional informaUon. 20. Attachments: Filing fee: x Property Plat: x BOP Sketch: Diverter Sketch: Drilling program: x Drilling fluid program: Time vs. depth pict: Refraction analysis: Seabed report: 20 AAC 25.050 requirements: 21. I herby certify that the foregoing is true and correct to the best of my knowledge: Signed: /'3~, c:.. (~\C'~--- Title: Drilling Manager Date: ~ Commission Use Only Permit Number I API number I ^pprov~/ i soo covo, - for other requirements CondiUons of approval Samples required: [ ] Yes ,~ No Mud log required: [ ] Yes ~p~ No Hydrogen sulfide measures [ ] Yes '~ No Directional survey required ~ Yes [ ] No Required working pressure forBOPE [ ]2M; [ ]3M; [ ]SM; [ ]1OM; [ ]15M Other: Original Signed By by order of Approved by David W. Johnston Commissioner the Commission Date:~ f( "~ '" ¢ ¢ Form 10-401 Rev. 12-1-85 Submit in triplicate UNOCALe I. Pump Kick-off Plug and Sidetrack Fish. Monopod Platform Monopod A-3 RD3 Kick-off Plug & Sidetrack General Information: Total Depth: Previous CSG: Hole Size: M.W.: 7246' MD/ 6156' TVD 9-5/8" Window @ 3,500' MD 8-1/2" 9.6PPG Top of Cement: Bottom of Cement: Kick-off Point: 6000' MD/5100' TVD 6550' MD/5532' TVD 6100' MD/5180' TVD Capacities: 8-1/2" Open hole: 2-7/8" TBG x 8-1/2" OH: 2-7/8" TBG Displacement: 2-7/8" TBG Capacity: 5" 19.5 lb/ft Drillpipe: 5" DP x 8-1/2" OH: 0.3941 ft3/ft or 0.0702 BBL/ft 0.3490 ft3/ft or 0.0622 BBL/ft 0.0126 ft3/ft or 0.00224 BBL/ft 0.00579 BBL/ft 0.01776 BBL/ft 0.0459 BBL/ft Excess Requirements: Kick-off Slurry: 100 % excess in open hole.. Kick-off Plug Slurry Data: Hole Volume: Total Cement Volume: Total sacks: Slurry Weight: Cement Yield: 217 ft3 or 38.6 BBLS 433 ft3 or 77 BBLS (Includes 50% Excess) 370 sxs 15.8 lb/gal 1.17 ft3/sk RECEIVED '! 'i9.9 . P, faska. Oil & Gas Cons, Commissiorl Anchorage RIH PU 2-7/8" Tubing cement stinger. Drift tubing while PU. . Continue to RIH with 2-7/8" Tubing. Break circulation every 1000' while running in hole. Wash down from 4500' to 6550'. 3. Circulate bottoms up, while reciprocating pipe. 4. RU Dowell's cement lines and pressure test to 250/3,500 psi with Inlet water. De Pump the following schedule using cementing unit. Reciprocate pipe slowly. MTM X:MONA3KO.DOC Page 1 of 2 5/20/97/2:41 PM UNOCAL ) Monopod Platform Monopod A-3 RD3 Kick-off Plug & Sidetrack Note: Pump Schedule: Displacement is being left short to overbalance cement inside TBG. Pump Displacement withDowell. Volume 15 BBLS 8.4 PPG Weight Fluid Pumped Inlet water 77 BBLS 15.8 PPG Cement 1 BBL 8.4 PPG Inlet water 101 BBLS 9.6 PPG Mud 6. After one complete circulation, POOH with cement string. . . MU the following drilling assembly: 8-1/2" Hughes ATMGS-09 6-3/4" M1/C Mud Motor set @ 1.30 8 3/8" Stabilizer 6-9/16" Navitrack MWD 6-7/8" Hang-off Sub 1 jts of 5" HWDP 6-1/4" Drilling Jar/Bumper Sub Combo 39 jts of 5" HWDP RIH with BHA. Rabbit drillpipe while RIH. . Side track well fish from kick off plug @ 6268' and drill 8-1/2" hole to8525' based on the following dh'ectional program. Complete well as proposed on this Permit To Drill. For additional supporting information please refer to previous program & data submitted in A3-RD2 Permit To Drill. MTM X:MONA3KO.DOC Page 2 of 2 5/20/9712:41 PM MONOPOD PLATFORM WELL # A-3RD 3 TRADING BAY FIELD ROTARY KELLY BUSHING (RKB) Elev. 101' DRILL DECK LEVEL Elev. 75' PRODUCTION DECK LEVEL Elev. 56' SEA LEVEL (MLW) Elev. 0' MUD LINE Elev. -62' 20" Structural Casing @ 227' RKB (64'BML) 16" 75g J-55 Conductor Casing @ 413' 13-3/8" 61# J-55 BTC Surface Casing @ 1870' 9-5/8" 47# NS0 BTC Intermediate Casing @ 3493' (KOP) 7" 29# L-80 BTC Production Casing @ 8510 ~ ~ 2t~ 21~ ~1~ 2t~ ~ ~ ~t~ ~ ~t~ .... UNOCAL.- 50% ..... FORCENERGY - 50% ,~ * ~ · I 2850 AC ~ PRq~OSED LOCATION ' ' ' ~ * PRO~ P~T ~P ~ ~"'~_j ~_ * ~ ~L'18781 ,, ~ .... ~' 80' 64'if 2521o0o i i UNOCAL finch i Dote plotted : 20-Uoy~-g7:~ r ..... ,isi-3Rd ,~l~Ver,. #2.j: i Structur, : ~ONOPOD Platform W,II : AlRd~ J C~rainot~ are in fe~ r~e slot ~20. J J Field : Trading Bay Field Location : TBU, Cook InJef, Alaska V~ical Oep~s are reference w~lhead.~ ~ 5250 5400 5550 5700 ~ ~850 ~ 6~co4 -- 6~C0 6450 S600 I v 6750 7C50 7200 UNOCAL ) East (feet) -> go0 1000 ! 1 O0 1200 1300 1400 ? 500 1600 1700 1800 ' ' ~ ' ' ' ' ' 3700 3600 35OO 3400 3300 3200 31 O0 3000 2900 2800 2700 2600 2500 2400 2300 2200 7350 t , , , , , , , , , , , 2700 2850 3000 3150 3300 3450 3500 3750 3900 Verficol Secfion (feei) -> UNOCAL MOW~ Platform slot #20 Tra~ing Bay Field TBU, C~ok Inlet, Alaska SURVEY LISTING by Baker Hughes INTEQ Ycx~r ref : PMSS <5982 - 8525'> Our ref : svy5566 License : Date printed : 19-May-97 Date created : 27-Apr-97 Last revised : 15-May-97 Field is centre~ on n60 53 32.779,w151 34 32.077 Structure is centre~ on n60 53 32.779,w151 34 32.077 Slot location is n60 53 48.692,w151 34 43.316 Slot Grid coordinates are N 2523129.377, E 218880.709 Slot Local coordinates are 1616.00 N 556.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North UNOCAL HONOPCO Ptatform,A3Rd~L~ ~ Trading Bay Fietd,TBU, Cook Intel, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth SURVEY LISTING Page 1 Your ref : PMSS <5982 - 8525'> Last revised : 15-May-97 R E C T A N G U L A R Dogleg Vert C 0 0 R D I N A T E S Deg/lOOft Sect 5982.00 37.50 19.80 5082.34 2248.33 N 1436.05 E 0.70 2650.73 6023.00 35.40 16.70 5115.32 2271,45 N 1443,69 E 6.81 2674.85 6053.00 35.00 15.88 5139.84 2288.04 N 1448,54 E 2.06 2691.89 6103.00 34.20 13.95 5181.00 2315.48 N 1455.85 E 2.71 2719.75 6133.00 33.90 10.7'5 5205.85 2331.88 N 1459.44 E 6.09 2736.06 6165.00 34.30 9.17 5232.35 2349.55 N 1462.54 E 3.01 2753.29 6195.00 34.10 6.27 5257.17 2366.25 N 1464.81 E 5.47 2769.29 6226.00 33.90 2.72 5282.87 2383.53 N 1466.17 E 6.44 2785.40 6259.00 33.80 1.54 5310.28 2401.90 N 1466.85 E 2.01 2802.20 6305.00 33.90 1.13 5348.48 2427.51 N 1467.45 E 0.54 2825.47 6351.00 34.10 2.42 5386.62 2453.22 N 1468.24 E 1.63 2848.92 6381.00 34.10 2.45 5411.46 2470.03 N 1468.96 E 0.06 2864.32 6411.00 34.00 2.42 5436.31 2486.81 N 1469,67 E 0.34 2879.71 6444.00 33.90 3.55 5463.69 2505.21 N 1470.63 E 1.94 2896.66 6489.00 33.60 4.26 5501.10 2530.15 N 1472.33 E 1.10 2919.81 6537.00 33.80 3.51 5541.04 2556.73 N 1474.14 E 0.96 2944.47 6582.00 33.80 0.67 5578.44 2581.74 N 1475.05 E 3.51 2967.34 6612.00 34.30 358.51 5603.29 2598.53 N 1474.93 E 4.36 2982.37 6654.00 34.50 357.70 5637.95 2622.25 N 1474.14 E 1.19 3003.32 6723.00 35.60 353.55 5694.44 2661.73 N 1471.10 E 3.80 3037.45 6816.00 36.40 345.37 5769.72 2715.36 N 1461.09 E 5.24 3081.22 6862.00 35.40 341.04 5806.99 2741.17 N 1453.31 E 5.93 3100.98 6909.00 35.10 337.20 5845.38 2766.51 N 1443.65 E 4.76 3119.49 6955.00 34.80 335.48 588~.08 2790,64 N 1433.07 E 2.24 3136.52 7004.00 34.80 331.40 5923.32 2815.65 N 1420.58 E 4.75 3153.48 7033.00 35.00 328.09 5947.11 2829.97 N 1412.22 E 6.57 3162.68 7098.00 35.40 326.76 6000.23 2861.54 N 1392.05 E 1.33 3182.16 7149.00 34.90 328.83 6041.93 2886,38 N 1376.40 E 2.53 3197.59 7192.00 35.40 329.80 607'/'.09 2907.67 N 1363.76 E 1.74 3211.16 7232.00 35.10 332.68 6109.75 2927,90 N 1352.66 E 4.22 3224.45 7286.00 34.80 333.76 6154.02 2955.52 N 1338.72 E 1.27 3243.13 7331.00 33.10 336.49 6191.35 2978,31 N 1328.14 E 5.07 3258.94 7379.00 33.40 3~6.07 6231.49 3002.40 N 1317.55 E 0.79 3275.93 7425.00 33.60 335,62 6269.85 3025.57 N 1307,16 E 0.69 3292.17 7472.00 33.60 337,17 6308.99 3049.40 N 1296.75 E 1.82 3309.00 7518.00 31.20 338,57 6347.83 3072,22 N 1287.45 E 5.47 3325.41 7566.00 30.80 338.76 6388.98 3095,25 N 12T8.46 E 0.86 3342.14 7610.00 31.00 338.15 6426.73 3116,27 N 1270.16 E 0.84 3357.37 7658.00 31.20 338.86 6467.83 3139.34 N 1261.08 E 0.87 3374.10 7701.00 30.10 340,57 6504.82 3159.90 N 1253.47 E 3.26 3389.22 7752.00 29.80 341.99 6549.01 3184.01 N 1245.30 E 1.51 3407.28 7800.00 30.00 341,74 6590.63 3206.75 N 1237.85 E 0.49 3424.4~ 7846.00 30.40 341.8~ 6630.38 3228.73 N 1230.62 E 0.88 3440.99 7892.00 30.50 339,89 6670.04 3250.75 N 1222.98 E 2.15 3457.41 7939.00 30.90 339,77 6710.45 3273.27 N 1214.70 E 0.86 3474.00 8525.00 30.90 339.77 7213.28 3555.64 N 1110.64 E 0.00 3681.88 Projected Data - NO SURVEY ALL data is in feet unless otherwise stated. Coordinates from slot #20 and TVD from wellhead (101.00 Ft above mean sea level). Sottom hole distance is 5725.07 cn azimuth 17.35 degrees from wellhead. Vertical section is from wellhead on azimuth 26.08 degrees. Calculation uses the minim~xn curvature method. Presented by Baker Hughes [NTEQ UNOCAL MOflOPOD PLatform,A3Rd~ ~ Trading Bay Fietd,TBU, Cook InLet, ALaska ~JRVEY LISTING Page 2 Your ref : PMSS <5982 - 8525~> Last revised : 15-May-97 Co~ents in wel[path MD TVO Rectan<Ju[ar Coords. Comment 8525.00 721].28 3555.64 N 1110.64 E Projected Data - NO SURVEY Targets associated with this ~eLLpath Target name Geographic Location T.V.D. ~ectanguLar Coordinates Revised A3rd~Z St~ 25-Apr-9 5T57.00 2719.31N 1442.20E 25-Apr-97 Unocal Alaska Resour Unocal Corporation 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL June 26,1997 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Trading Bay Field Permit To Drill and Request for Administrative Approval Dear Chairman Johnston: Union Oil Company of California (Unocal), as Operator of the Monopod Platform, requests your approval to drill A-3rd3 and further requests Administrative Approval, pursuant to Rule 9, Conservation Order No. 93. In triplicate, is our application for Permit to Drill ADL 18731- A-3rd3 (form 10-401) pursuant to 20 AAC 25.005 and our check No. 2002324 in the amount of $100.00 as required under 20 AAC 25.005 (c)(1). Unocal intends to drill the ADL 18731- A-3rd3 well from the Monopod Platform into the Tyonek C & D Pool of the Trading Bay Field for recovery of Tyonek production. The specific location, interval and depth are as follows: 1. Surface Location: 1616'FSL & 556'FEL, Sec. 4, T9N-R13W, SM. 2. Top of Prod. Interval: 862'FNL & 874'FWL, Sec. 3, T9N-R13W, SM. 3. Total Depth: 109'FNL & 555'FWL, Sec. 3, T9N-R13W, SM. If you require additional information, Please contact undersigned at (907) 263-7882 or, Neal MaGee Drilling Dept. at 263-7671. ,-, Very truly yours, UNION OIL COMPANY OF CALIFORNIA, d.b.a. UNOCAL RickD Cross RECEIVED dUL ]1997 Alaska Oil & Gas Cons. Commissioil Anchorage FOR INQUIRIES CONTACT LOCATION WHERE INVOICES WE~-SUBMt"FrED VEN~-'~-.R NO. DATE CHECK'NO.. 1~1548 05-30-97 2002324 ..'":[:)ATE'... EDiT ~ UOH GROSS: DISCOUNT NET 27-MAY-97 DRILLPERMITA3RD 05973001373 100.00 100.00 FORM 4-2B181 (REV. 11-95) PRINTED IN U.S.A. Bi:TACH RTIJB RF:FORF DFPt3RITINP~ P, NI:P,,K 10 0 · 0 0 10 0 · 0 0 WELL PERMIT CHECKLISTco,~A.Y/'~/,~./ w~L,, NAME T~).~k'"- /~--3 /''~'' ~g;~3 :PROGRAH: e×pl'] dev~ redrl~servF! wellbore segn ann disp para reqFII ADMINISTRATION APPR DATE ENGINEERING 1 2 3 4 5 6 7 8 9 10 ll. 12. 13. Permit fee attached .................. N Lease number appropriate ............... N Unique well name and number .............. N Well located in a defined pool ............. N Well located proper distance from drlg unit boundary. . N Well located proper distance from other wells ..... N Sufficient acreage available in drilling unit ..... N If deviated, is wellbore plat included ........ N Operator only affected party .............. N Operator has appropriate bond in force ......... N Permit can be issued without conservation order .... N Permit can be issued without administrative approval. . N Can permit be approved before 15-day wait ....... N REMARKS APPR APPR GEOLOGY ],4. 15. 16. 17 18 19 20 21 22 23 24 25 26 27 28 29 Conductor string provided ................ Y N Surface casing protects all known USDWs ......... Y N CMT vol adequate to circulate on conductor & surf csg. . Y N CMT vol adequate to tie-in long string to surf csg . . . Y N CMT will cover all known productive horizons ...... ~ N Casing designs adequate for C, T, B & permafrost .... ~ N Adequate tankage or reserve pit ............. .~ N If a re-drill, has a 10-403 for abndnmnt been approved. N Adequate wellbore separation proposed .......... Q N If diverter required, is it adequate .......... ~~_ ~i~e~ ~r~g~a~ ~c?e~a~i~ ~ ~q~i~ ~i~t.a~e~u?t~ i~ ~ -- ~eP~f~i~m~a~;~p~e~-~ ~psig'~ ~ ~'/ Work will occur without operation shutdown ....... Is presence of H2S gas probable ............. Y 30. Permit can be issued w/o hydrogen sulfide measures .... Y Data presented on potential overpressure zones ..... Y/'N 32.31. Seismic analysis of shallow gas zones ......... 33. Seabed condition survey (if off-shore) ....... ~W'. Y N 34. Contact name/phone for weekly progress reports . .~-. . Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: HOWldlf - A:\FORMS\cheklist rev 01/97 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * * . ****************************** * ....r ....................... * * ....... SCHLUMBERGER ....... * * ............................ . COMPANY NAME : UNION OIL COMPANY OF CALIFORNIA WELL NAME : MONOPOD A-3 RD 3 FIELD NAME : TRADING ~AY BOROUGH : KENAI STATE : ALASKA API NUMBER : 50-733-10057-02 REFERENCE NO : 97211 * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : UNION OIL COMPANY OF CALIFORNIA WELL NAME : MONOPOD A-3 RD 3 FIELD NAME : TRADING BAY UNIT BOROUGH ' KENAI STATE : ALASKA API NUMBER : 50-733-10057-02 REFERENCE NO : 97211 LIS Tape Verif~ ~ion Listing · Schlumberger Alaska Computing Center 19-MAY-1997 08:51 PAGE: * * * * REEL HEADER * * * * SERVICE NAME : EDIT DATE · 97/05/19 ORIGIN · FLIC REEL NAME : 97211 CONTINUATION # : PREVIOUS REEL : COMMENT · UNOCAL, TBU A-3 RD3, MCARTHUR RIVER, 50-733-10057-02 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/05/19 ORIGIN : FLIC TAPE NAME : 97211 CONTINUATION # '. 1 PREVIOUS TAPE : COMMENT : UNOCAL, TBU A-3 RD3, MCARTHUR RIVER, 50-733-10057-02 TAPE HEADER TRADING BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: MONOPOD A- 3 RD 3 API NUMBER: 507331005702 OPERATOR: UNION OIL COMPANY OF CALIFORNI LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 19-MAY-97 JOB NUMBER: 97211 LOGGING ENGINEER: MOTHERWELL OPERATOR WITNESS: MIKE McCAUL SURFACE LOCATION SECTION: 4 TOWNSHIP: 9N RANGE: 13W FNL: FSL : FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 101. O0 DERRICK FLOOR: 100. O0 GROUND LEVEL: WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8. 500 7. 000 8430.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Veri£~ .cion Listing Schlumberger Alaska Computing Center BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH $ 19-MAY--997 08:51 .......... EQUIV~-L. ENT UNSHiFTED DEPTH .......... THIS IS THE DATA FROM T~HE TDT-P LCGGED 8-MAY-97. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION ' O01CO1 DATE : 97/05/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE lv73I~BER 1 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SO?4~ARY VENDOR TOOL CODE START DEPTH TDTP 8421.0 $ LOG H~ER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) '. BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAIV~4A RAY STOP DEP_-Y~ .......... 6780.0 8-MAY-97 7C0-427 304 08-MAY-97 8417.0 8421.0 6800.0 8414.0 1800.0 NO TOOL NUMBER ATC-CB LIS Tape Veri~_ cion Listing Schlumberger Alaska Computing Center 19-MAY-1997 08:51 PAGE: TDTP THERMAL DECAY TDT- P BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 8.500 8430.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) .. GAS~OIL RATIO: CHOKE (DEG) : DISPLACED SEA WATER 68.0 129.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): 1.0 REMARKS: 5.87" GAGE RING RUN TIED INTO BOREHOLE COMPENSATED SONIC LOG OF 3-MAY-1997 $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 LIS Tape Verif_ .ion Listing · Schlumberger Alaska Computing Center 19-MAY-!997 08:5£ PAGE: TYPE REPR CODE VALUE 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ND?,IB SAMP ELEM CODE (HEX) DEPT FT 532074 O0 000 O0 0 i 1 ! 4 68 0000000000 SIGMTDTP CU 532074 O0 000 O0 0 1 1 1 4 68 0000000000 TPHI TDTP PU 532074 O0 000 O0 0 ! 1 ! 4 68 0000000000 SBHF TDTP CU 532074 O0 000 O0 0 1 1 1 4 68 0000000000 SBHNTDTP CU 532074 O0 000 O0 0 1 1 1 4 68 0000000000 SIGC TDTP CU 532074 O0 000 O0 0 1 1 1 4 68 0000000000 SIBH TDTP CU 532074 O0 000 O0 0 ! 1 ~ 4 68 0000000000 TRAT TDTP 532074 O0 000 O0 0 ! 1 ~ 4 68 0000000000 SDSI TDTP CU 532074 O0 000 O0 0 i 1 i 4 68 0000000000 BACK TDTP CPS 532074 O0 000 O0 0 i 1 ~ 4 68 0000000000 FBAC TDTP CPS 532074 O0 000 O0 0 1 1 ! 4 68 0000000000 TCANTDTP CPS 532074 O0 000 O0 0 1 1 ~ 4 68 0000000000 TCAF TDTP CPS 532074 O0 000 O0 0 1 1 ~ 4 68 0000000000 TCND TDTP CPS 532074 O0 000 O0 0 1 1 ! 4 68 0000000000 TCFD TDTP CPS 532074 O0 000 O0 0 1 1 ! 4 68 0000000000 TSCN TDTP CPS 532074 O0 000 O0 0 1 1 ~ 4 68 0000000000 TSCF TDTP CPS 532074 O0 000 O0 0 1 1 1 4 68 0000000000 INND TDTP CPS 532074 O0 000 O0 0 1 1 i 4 68 0000000000 INFD TDTP CPS 532074 O0 000 O0 0 1 1 ! 4 68 0000000000 GR TDTP GAPI 532074 O0 000 O0 0 1 1 1 4 68 0000000000 TENS TDTP LB 532074 O0 000 O0 0 1 1 ! 4 68 0000000000 CCL TDTP V 532074 O0 000 O0 0 1 1 ~ 4 68 0000000000 ** DATA ** DEPT. 8421 . 000 SIGM. TDTP 12. 118 TPHI. TDTP 18. 239 SBHF. TDTP SBHIV. TDTP 56. 250 SIGC. TDTP 0. 793 SIBH. TDTP 67.940 TRAT. TDTP SDSI. TDTP 0. 177 BACK. TDTP 130. 740 FBAC. TDTP 31. 614 TCAN. TDTP TCAF. TDTP 44190.281 TCND. TDTP 24349. 047 TCFD. TDTP 9152. 020 TSCN. TDTP TSCF. TDTP 3997. 066 INND. TDTP 2064 . 001 INFD. TDTP 353. 211 GR. TDTP 45.752 1.516 85510.641 7734.546 0.000 LIS Tape Veri~_ ~ion Listing Schlumberger Alaska Computing Center 19-MAY-1997 08:5~ PAGE: TENS. TDTP 5185. 000 CCL. TDTP 0.000 DEPT. 8000. 000 SIGM. TDTP 18. 522 TPHI. TDTP 33. 280 SBHF. TDTP SBHN. TDTP 52. 554 SIGC. TDTP 1 . 374 SIBH. TDTP 64. 762 TRAT. TDTP SDS I . TDTP O . 374 BA CK. TDTP 13 6.041 FBA C . TDTP 27.149 TCAN. TDTP TCAF. TDTP 18792.250 TCND. TDTP 22550. 766 TCFD. TDTP 6841. 224 TSCN. TDTP TSCF. TDTP 2193. 830 INND. TDTP 204 6. 280 INFD. TDTP 358. 797 GR. TDTP TENS. TDTP 5015. 000 CCL. TDTP O. 000 DEPT. 7500. 000 SIGM. TDTP 15. 032 TPHI. TDTP 30. 444 SBHF. TDTP SBHN. TDTP 49. 097 SIGC. TDTP 1 . 385 SIBH. TDTP 56. 684 TRAT. TDTP SDSI . TDTP O . 305 BACK. TDTP 174. 055 FBA C . TDTP 31 . 161 TCAN. TDTP TCAF. TDTP 22508. 656 TCND. TDTP 23594 . 883 TCFD. TDTP 7268. 985 TSCN. TDTP TSCF. TDTP 2648. 130 INND. TDTP 1841. 959 INFD. TDTP 342. 435 GR. TDTP TENS. TDTP 4435. 000 CCL. TDTP O. 000 DEPT. 7000. 000 SIGM. TDTP 12. 739 TPHI. TDTP 25. 644 SBHF. TDTP SBHN. TDTP 48. 576 SIGC. TDTP O. 838 SIBH. TDTP 54. 789 TRAT. TDTP SDSI. TDTP O. 224 BACK. TDTP 187. 557 FBAC. TDTP 31 . 785 TCAN. TDTP TCAF. TDTP 31805. 852 TCND. TDTP 26559. 426 TCFD. TDTP 8923 . 260 TSCN. TDTP TSCF. TDTP 3735.618 INND. TDTP 1960. 058 INFD. TDTP 377. 802 GR. TDTP TENS. TDTP 4195. 000 CCL. TDTP O. 000 DEPT. 6780. 000 SIGM. TDTP 26. 008 TPHI. TDTP 54 . 333 SBHF. TDTP SBHiN. TDTP 47. 428 SIGC. TDTP 1. 318 SIBH. TDTP 53. 781 TRAT. TDTP SDSI. TDTP O. 684 BACK. TDTP 185. 492 FBAC. TDTP 32. 684 TCAN. TDTP TCAF. TDTP 11238. 113 TCND. TDTP 19189. 637 TCFD. TDTP 4977. 424 TSCN. TDTP TSCF. TDTP 1254. 400 INND. TDTP 1843. 364 INFD. TDTP 331. 581 GR. TDTP TENS. TDTP 4095. 000 CCL. TDTP O. 000 38.727 1.765 47473.461 5542.109 45.907 39.560 1.841 56558.438 6654.065 33.706 42.781 1.785 73830.797 8671.475 23.411 37.504 2.061 36288.508 4021.880 39.158 ** END OF DATA ** * * * * FILE TRAILER * * * * FILE NAME : EDIT .001 SERVICE : FLIC VERSION · 0 O1 CO1 DATE · 97/05/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/05/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verify, .cion Listing Schlumberger Alaska Computing Center 19-MAY-1997 08:51 PAGE: 6 FILE HEADER FILE NIIMBER 2 RAW CURVES Curves and log header data for each pass in se~srate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH TDTP 8421.0 $ LOG HEADER DATA STOP DEPTH 7495.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): f-MAY-97 730-427 304 08-MAY-97 ~417.0 ~421.0 6800.0 ~414.0 l~O0.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAN2~A RAY TDTP THERMAL DECAY $ TCOL NUMBER ATC-CB TDT-P BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : ~.500 ~430.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : EiSPLACED 68.0 ~29.0 S~& WATER NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): W-?~RMAL S~D~STONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZO,%~E LIS Tape Verif= .cion Listing Schlumberger Alaska Computing Center 19-MAY-1997 08:51 PAGE: TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): 1.0 REMARKS: 5.87" GAGE RING RUN TIED INTO BOREHOLE COMPENSATED SONIC LOG OF 3-MAY-1997 $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NU~IB SAMP ELEM CODE (HEX) DEPT FT 532074 O0 000 O0 0 2 1 1 4 68 0000000000 SIGMTDTP CU 532074 00 000 O0 0 2 1 1 4 68 0000000000 TPHI TDTP PU 532074 O0 000 O0 0 2 1 1 4 68 0000000000 SBHF TDTP CU 532074 O0 000 O0 0 2 1 1 4 68 0000000000 SBHN TDTP CU 532074 O0 000 O0 0 2 1 1 4 68 0000000000 SIGC TDTP CU 532074 O0 000 O0 0 2 1 1 4 68 0000000000 SIBH TDTP CU 532074 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Veri~ ~ion Listing Schlumberger Alaska Computing Center 19-MAY-1997 08:5~ PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NLY.~B SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NDT.~B SAMP EL~4 CODE (HEX) TRAT TDTP 532074 O0 000 O0 0 2 1 1 4 68 0000000000 SDSI TDTP CU 532074 O0 000 O0 0 2 1 1 4 68 0000000000 BACK TDTP CPS 532074 O0 000 O0 0 2 ! 1 4 68 0000000000 FBAC TDTP CPS 532074 O0 000 O0 0 2 1 1 4 68 0000000000 TCANTDTP CPS 532074 O0 000 O0 0 2 1 1 4 68 0000000000 TCAF TDTP CPS 532074 O0 000 O0 0 2 1 1 4 68 0000000000 TCND TDTP CPS 532074 O0 000 O0 0 2 1 1 4 68 0000000000 TCFD TDTP CPS 532074 O0 000 O0 0 2 1 1 4 68 0000000000 TSCN TDTP CPS 532074 O0 000 O0 0 2 1 1 4 68 0000000000 TSCF TDTP CPS 532074 O0 000 O0 0 2 1 1 4 68 0000000000 INND TDTP CPS 532074 O0 000 O0 0 2 1 1 4 68 0000000000 INFD TDTP CPS 532074 O0 000 O0 0 2 1 1 4 68 0000000000 GR TDTP GAPI 532074 O0 000 O0 0 2 1 1 4 68 0000000000 TENS TDTP LB 532074 O0 000 O0 0 2 1 1 4 68 0000000000 CCL TDTP V 532074 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 8421. 000 SIGM. TDTP 12. 241 TPHI. TDTP 18. 975 SBHF. TDTP SBHN. TDTP 56. 602 SIGC. TDTP O. 620 SIBH. TDTP 69. 046 TRAT. TDTP SDSI. TDTP O. 338 BACK. TDTP 256. 295 FBAC. TDTP 72. 629 TCAN. TDTP TCAF. TDTP 15688.172 TCND. TDTP 23803. 824 TCFD. TDTP 9046. 393 TSCN. TDTP TSCF. TDTP 3936.414 INND. TDTP 1896.737 INFD. TDTP 367.996 GR. TDTP T~-~TS. TDTP 5035. 000 CCL. TDTP O. 000 DEPT. 8000. 000 SIGM. TDTP 17. 449 TPHI. TDTP 33. 203 SBHF. TDTP SBHN. TDTP 51. 970 SIGC. TDTP 2. 220 SIBH. TDTP 63 . 995 TRAT. TDTP SDSI. TDTP O. 817 BACK. TDTP 206. 666 FBAC. TDTP 37.134 TCAN. TDTP TCAF. TDTP 7171 . 439 TCND. TDTP 22607.129 TCFD. TDTP 6778. 419 TSCN. TDTP TSCF. TDTP 2126. 085 INND. TDTP 2079. 057 INFD. TDTP 360. 957 GR. TDTP TENS. TDTP 4835. 000 CCL. TDTP 0. 000 DEPT. 7500. 000 SIGM. TDTP 15.218 TPHI. TDTP 30. 551 SBHF. TDTP SBHN. TDTP 46.330 SIGC. TDTP 1 . 406 SIBH. TDTP 50. 827 TRAT. TDTP SDSI. TDTP O. 578 BACK. TDTP 209. 956 FBAC. TDTP 35. 255 TCAN. TDTP TCAF. TDTP 8984. 822 TCND. TDTP 23408. 020 TCFD. TDTP 7119.105 TSCN. TDTP TSCF. TDTP 2512.159 INND. TDTP 1817.103 INFD. TDTP 344. 429 GR. TDTP TENS. TDTP 4465. 000 CCL. TDTP O. 000 DEPT. 7483.500 SIGM. TDTP 26.604 TPHI.TDTP 46.735 SBHF. TDTP SBHN. TDTP 46.003 SIGC. TDTP 2.805 SIBH. TDTP 50.549 TRAT. TDTP SDSI. TDTP 1.089 BACK. TDTP 203.126 FBAC. TDTP 40.422 TCAN. TDTP TCAF. TDTP 5459.303 TCND. TDTP 18484.113 TCFD. TDTP 4888.755 TSCN. TDTP TSCF. TDTP 1054.142 INND. TDTP 1796.056 INFD.TDTP 310.300 GR.TDTP TENS. TDTP 4490.000 CCL. TDTP -999.250 40. 631 1. 536 30919. 766 7758. 266 165. 700 36.054 1.803 18612.445 5517.950 61.688 46.659 1.866 22845.633 6387.646 41.352 40.112 1.904 17783.883 3289.758 29.035 ** END OF DATA ** LIS Tape Veril cion Listing Schlumberger Alaska Computing Center 19-MAY-1997 08:5~ PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE : 97/05/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/05/19 ORIGIN : FLIC TAPE NAME : 97211 CONTINUATION # : 1 PREVIOUS TAPE COM~IENT : UNOCAL, TBU A-3 RD3, MCARTHUR RIVER, 50-733-10057-02 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/05/19 ORIGIN : FLIC REEL NAME : 97211 CONTINUATION # : PREVIOUS REEL : COk~FdFT : UNOCAL, TBU A-3 RD3, MCARTHUR RIVER, 50-733-10057-02
