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Home My WebLink About168-0491. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Run Pkr Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: N2 FCO & Chem squeeze Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10,522 feet see WBS feet true vertical 9,885 feet see WBS feet Effective Depth measured 4,175 feet N/A feet true vertical 3,695 feet N/A feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)3-1/2" 9.2#/N-80 3992' MD 3559' TVD Packers and SSSV (type, measured and true vertical depth)DLH Packer; N/A 2886' MD; N/A 2536' TVD; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 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 Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Ryan Rupert Authorized Title:Operations Manager Contact Email: Contact Phone:777-8503 ryan.rupert@hilcorp.com Senior Engineer:Senior Res. Engineer: 8,160psi Burst 58' 1,295' 5,750psi 2,730psi Collapse 1,130psi 3,090psi 7,020psi Casing Structural 20" 13-3/8" 9-5/8" Length 58' 1,317' 6,027' Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: 210 Casing Pressure Liner 4,701' 0 9,885' 0 Representative Daily Average Production or Injection Data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-411 35 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 60 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 168-049 50-133-20121-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 00 Kenai Deep Unit (KDU) 2(21-8) N/A FEDA028142 6,027' Plugs Junk measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Kenai Gas Field / Sterling 3 GasN/A measured TVD Tubing PressureOil-Bbl measured true vertical Packer 7" 5,412' WINJ WAG 0 Water-Bbl MD 58' 1,317' 10,522' 0 t Fra O Run 6. A G L PG , R e Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 11:08 am, Jan 19, 2021 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2021.01.18 13:16:42 -09'00' Taylor Wellman DSR-1/19/21 SFD 1/25/2021 RBDMS HEW 1/27/2021 N2 FCO & Chem squeezee gls 2/4/21 Perforate Rig Start Date End Date 12/15/20 12/28/20 Daily Operations: 12/16/2020 - Wednesday Travel to location, Contact DSO, initiate permit, PJSM with all parties involved. PU injector head, make up CC, pull test 15K, Make up rest of tool string. (CTC 1.75" X .085') (DFCV 1.75" X 1.17') (STINGER 1.75" X 4') (DJN 1.75" X .580') TOL=5.835'. Head to well, stab on well, pt low/high 250/4,000. Open well, swab 21 turns, T/I/O= 240/200/0. RIH, @ 300' Having an issue with oil pressure on coil tractor. POOH trouble shoot tractor. Shut down tractor, check oil. Called mechanic waiting on phone call back. Got the call back and all clear to RIH. WT CK 1,000'=3k , 2,500'= 6.5k, 3,500'=9k. Tag fill at 3,815' CTMD. PU WT 10k. Mixing 6% KCL. Come online with 6% KCL at 1 bpm @ 28 bbls away coil pressured up to 3,900 psi, possible ice plug at the nozzle. POOH to check nozzle leaving 3,800 psi on coil. At surface, coil pressure fell to zero, try to pump out to the return tank before popping off well. Established returns to tank with well shut in, pump for 5 min, open well back up, RIH. @ 3,815' N2 at 600 scfm, .6 bpm fluid take a 50' bite @10 fpm, chase up hole at 30 fpm to 3,800'. Start digging taking 50' bites chasing up to the TT. N2 @ 600 SCFM, .8 BPM. CTP 2850, WHP 20-80 PSI. Swap to foam. Pump Rate .6 bpm, N2 @ 600 scfm. WHP 35, IA 250 , OA 0, CTP 2,950 PSI, taking 50% losses into formation once we uncovered the A8 sands. PU to 1,300' got full returns back to tank. Work our way back down trying to maintain good returns. @ 4,160' returns are looking good, WHP 80, IA 250, OA 0. Continue cleaning down to 4,275'. Chase last bite out of hole pumping .25 bpm, 800 scfm. WHP 20, IA 230, OA 0. Pumped 163 bbls 6% KCL, 87 bbls 6% with F104/Flovis for foam. Tagged up, swab shut, bleed down, blow down, pop off well. Stack lubricator and injector on deck. Secure well and location for the night. Job in progress. Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KDU-02 50-133-20541-00 204-107 12/15/2020 - Tuesday Travel to location. Contact DSO, inspect location, Fill out permit, PJSM with SLB, Cruz and Fairweather. MIRU. Rig up hardline to choke, return tanks, pump and bops. Run hydraulic lines to bop and injector head. Stab pipe into injector, change packoffs, do chain inspection. Test BOPE as per Hilcorp & AOGCC requirements, witnessed waived 12/14/2020 @ 1417 PM by AOGCC Inspections Supervisor Jim Regg, 250/4,000. Emailed BOPE Test Report to AOGCC. Rig up N2 and tanker, spot hot oil unit, finish loading upright with 400 bbls filtered FW. Roll upright heating to 130* Secure location, SDFN. Job in progress CTU Foam FCO Rig Start Date End Date 12/15/20 12/28/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KDU-02 50-133-20541-00 204-107 12/17/2020 - Thursday 12/21/2020 - Monday Travel to location, Contact DSO, inspect location. Fill out permit. PJSM. Fire up equipment, get triplex rigged up, Pu injector, 10' lubricator and bops. Test BOPE as per Hilcorp & AOGCC requirements, witnessed waived 12/21/2020 @ 0829 AM by AOGCC Inspections Supervisor Jim Regg, 250/4,000. Emailed BOPE Test Report to AOGCC. Mix up 200 bbls 6% KCL, transfer to supply tank. Secure well and location for the night. Job on progress. Travel to location, contact DSO, inspect location. PJSM with SLB, HES, and Cruze crane operator. PU injector, 22' lubricator. Make up tool string. (CTC 1.75" X .085') (STINGER 1.75" X 4') (BDJSN 5/8" ball to plug hole on nozzle 1.75" X .580') TOL=4.665'. Stab on well, get triplex from ops, PT low/high 250/4,000. Open well, swab 21, WHP 250, IA 150, OA 0. RIH. HES MIRU. Tag @ 4,335' CTMD. Call town to discuss tag before we pump cement. Have PSJM with cement and coil crew. Line up to pump 5bbls FW into coil, shut down, pressure test low/high 500/4,500. 10:45 Cement wet, HES start batching up cement. Online with 15.7 ppg cement down coil @ 1 BPM, CTP 2,850, WHP 0, IA 150, OA 0. Pumped 10.6 bbls 15.7 ppg cement. HES offline, come online with SLB pump down coil with 23 bbls 6% kcl to displace cement. Coil pressure locked up at 33 bbls away. POOH to get some heat on the coil. At 3,400' coil pressure fell off and were able to circulate. RBIH parked @ 4,325', Cmt at the nozzle. 5 bbls FW. 10.6 bbls 15.7 ppg cement. 5 bbls. Let 1 bbl come out the nozzle, lay in at 12 fpm @ 1bpm. CTP 2,700, WHP 0, IA 250, OA 0. Cmt Laid in, estimated TOC is +/- 4,190' , POOH. 5 bbls FW. 10.6 bbls 15.7 ppg cement. 5 bbls FW. Followed with 33 bbls 6% KCL for displacement. Tagged up, swab shut, bleed down, pop off well. Break down tools, stack down lubricator and injector on deck. Secure well and location for the night. Job in progress. 12/18/2020 - Friday Travel to location, Contact DSO, inspect location. Get permit signed, PJSM. PU Injector, 22' lubricator, make up tools. (CTC 1.75" X .085') (DFCV 1.75" X 1.170') (STINGER 1.75" X 4') (JSN 1.75" X ,580') TOL= 5.835'. Stab on well, fluid pack for pt. low/high. 250/4,000. Open well, swab 21, T/I/O= 6/150/0. RIH. Tag at 4,100' CTMD. Come online with 6% KCL down the tubing for an injection test. 50 bbls away well pressured up to 950 psi. come offline monitor pressure while making phone calls to town. Call out tool company with motor and mill. POOH. Tagged up, swab shut, Bleed down, pop off well. Wait on tool compny. Tool company on location, PJSM, Make up CC, pull test to 25k, Make up rest of tools. Got call from enginner to shut down and wait for underreamer to be shipped up from lower 48. Blow reel down, secure well and location. Return in a few days to continue. Rig Start Date End Date 12/15/20 12/28/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KDU-02 50-133-20541-00 204-107 12/22/2020 - Tuesday Travel to location, Contact DSO, Inspect location. Initiate permit, PJSM. PU injector, 22' lubricator, make up CC. Pull test 25k, make up rest of tools. pt low/high 250/3,500. Head to well, Stab on well, pt full body low/high 250/4,000. (CTC 2.25" X .82') (DFCV 2.13" X .98') (BIDI JAR 2.13" X 5.60') (HYD DISCO 2.13" X 1.58') (CIRC SUB 2.13" X 1.05') (MUD MOTOR 2.13" X 10.44') (SPOKED UNDER REAMER 2.50" X 1.58') TOL= 22.05' (5/8" BALL FOR DISCO, 9/16" BALL FOR CIRC SUB) Under-ream blades 8.5". Open well, swab 22, T/I/O= 0/0/0. RIH. WT CK 3800'= 12,800lbs. RIH for dry tag. Tag @ 4,092' CTMD. Come on line with 6 % KCL at 1.2 bpm, WHP 200, IA 0, OA 0. Come on line with 6 % KCL at 1.2 bpm down the coil. WHP 200, IA 0, OA 0, CTP 3650 psi. Stall 4102' ctmd. PU to tbg tail. RBIH start milling at 4,100' under-ream to 4,125' RKB, pu wt 13k. pu for wiper trip. Under-ream down to 4,135'RKB, chase up for wiper trip to 4,000', RBIH start under-reaming at 4,135' RKB, Found hard spot at 4,135' RKB. Work area for few hours, Got down to 4,141' rkb, lost all returns. PU to 4,000', come offline with pump, pu into tbg making sure we can get into the tubing. pu clean. RIH for dry drift. Tag at 4,140' RKB. Shut choke, start under-reaming at 1.2 bpm, CTP 3228, WHP 0, IA 0, OA 0. Under-ream to 4,175' RKB. PU dry to 3,970' to make sure we could get into the tbg. RBIH for dry tag. Tag @ 4,175' RKB. POOH, Tagged up, swab shut, bleed down, pop off well. Break down tools. Under-reamer blades looked good. Minimal wear on blades. Make up nozzle. Stab back on well. Cool down N2, blow reel down to tanks, let coil bleed down, pop off well, break down tools. Stack down lubricator and injector head. Secure well and location for the night. Ready for Eline. Job in progress. under ream to 4175ft Rig Start Date End Date 12/15/20 12/28/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KDU-02 50-133-20541-00 204-107 12/23/2020 - Wednesday Travel to location. Arrive on location, fill out permit, contact DSO, inspect location, PJSM. Bleed down tree, pop tree cap off, put on WLV and riser, pu GR/CCL test wire. Good test, make up 20' dummy drift gun. Stab on well, get field triplex for pt. Triplex empty, call pad op for more meth. PT WLV and lubricator 250/2,500. Good test. Open well. RIH a few feet, lost tool string. Reason unknown at this time. Re-head wire. Make up GR/CCL, test wire. Good test. Make up lubricator, stab on well. PT WLV/lubricator low/high 250/2,500. RIH with 1-11/16th gun gamma, 7' wt bar. Tag at 4,093' uncorrected. 4,101' corrected. Pull log up to 2,800'. POOH. Send log to town for interpretation. Make 5' correction down. Top of fish at 4,119' corrected. TOL of fish 25'. Wait for slickline to show up to fish our tools. Slickline on location, PJSM, MIRU slickline. Make up fishing bha with 2.7" OD overshot. Stab on well, PT wlv and lub. RIH tag fish at 4,124' SLM, got friction bite or getting down along side of fish. POOH tools looked good and not sheared. Make up 2.5" JD, stab on well. RIH, tag fish at 4,122' SLM. try multiple times to latch fish. Same thing, friction bite or getting along side fish. POOH, at surface pop off, tools look good. Make up KJ & 2.7" OD overshot. RIH tag fish at 4,100' SLM, Got overpull pu 300lbs confirm we are latched up. Spang and jar hit 6 times, 7th jar hit fish came free. POOH, OOH with all tools and fish. Rig down SL, RU eline. GR/CCL, wt bar 20', 2-3/8", 60°, 5 spf razor gun, loaded with 5' of live charges. Stab on well, pt low/high 250/2,500. Open well, swab 22, T/I/O= 200/0/0. Tag at 4,120' Pull log up to 2,800'. Send log to town for review. Add a total of 5' correction to log. Send to town. Got the okay to shoot A8 ( Ben Siks). RIH to tag, pu get wt back and stop at 4,126.8' CCL Depth. CCL t/top shot 14.2', CCL t/bottom shot 19.2'. Shot the A8 from 4,141'-4,146'. Initial tubing psi 200 psi, 5min 200, 10 min 200, 15 min 200, Log up 200' no change in WHP. POOH, tagged up. WHP 200psi. Shut well, bleed down, pop off well. All shots fired. RDMO. Well ready for chemical squeeze. Job in progress. 12/24/2020 - Thursday Travel to location, Contact DSO, inspect location. PJSM. Get permit signed, fire up equipment. PU injector, 10' lubricator. Make up Tools. (CTC 2.25" X .3') (XO 2.13" X .25') (DFCV 1.75" X 1.08') (STINGER 1.75" X 4') (DJN 1.75" X .58') TOL=6.21'. Stab on well, Fluid pack for pt, low/high 250/4,000. Open well, swab 22, T/I/O= 150/0/0. RIH, Tag @ 4,144' CTMD. PU wt 13k, Move pipe up hole slowly while chemical is mixing. Come online with cocktail down coil, choke closed. Chemical at nozzle 33.3 bbls away, open choke to tank. Park at 4,144' CTMD. WHP 0, IA 0, OA 0, 30 bbls away, no change in psi. no returns to surface, IA 0, OA 0. CTP 2,650 psi. @ 1.5 bpm. 70 bbls away, 100 psi increase in CTP. CTP 2,752psi 1.5bpm, WHP 0, IA 0, OA 0. All chemical pumped into coil. @ 140 bbls injected WHP 0, IA 0, OA 0. Displace remainder of chemical with 33 bbls 6% KCL out of the coil for a total of 171 bbls injected. POOH, choke shut, WHP 0, IA 0, OA 0. Tagged up, swab shut. Cool down N2. Blow down reel to tank. Let coil bleed down, pop off well. Stack down tools, 10' lubricator, and injector. Have all tanks sucked out. Secure well and location. Let chemical soak 24 hrs. Will return Saturday to blow well down. Job on progress. CTU ... Eline Eline dropped tool string! Perf 4141-4146 ft Rig Start Date End Date 12/15/20 12/28/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KDU-02 50-133-20541-00 204-107 Travel to location, Contact DSO, inspect location. PJSM, MIRU E-Line. Make up 30' lubricator, GPT and 1 wt bar. Stab on well. PT WLV and lubricator low/high 250/2,500. Open well, swab 22 turns, T/I/O= 200/75/0. RIH. Find fluid level at 3,880'. Tag at 4,066' work wire multiple times trying to get deeper. No love. Log up to 3,200'. Send log to town for evaluation. Tag is 75' high. POOH. Tagged up, swab shut, bleed down, pop off well. Wait on Bailer to be hot shot to location. Bailer on location, make up 20' 2.25" Drive down bailer with CCL. Stab on well. pt low/high 250/2,500. Open well, swab 22, T/I/O= 200/75/0. RIH. Tag at 4,066', drive down bail for 30 min, pooh check bailer. Tagged up, swab shut, bleed down, pop off well. Bailer full of fluid and half cup of very fine sand/silt. RDMO E-Line. Secure well and location. 12/28/2020 - Monday Travel to location, Contact DSO, Inspect location. Get permit signed. PJSM. Rig down injector head, set on stand, rig down bops, hydraulic lines, hardline and return tanks. Load trailers with coil package. Drive pump and N2 unit to Beaver Creek. Lost oil pump to coil unit. Call Weaver Bros to come haul unit to SLB yard. 12/26/2020 - Saturday Travel to location, Contact DSO, inspect location, fill out permit, PJSM. Fire up equipment, Pu injector, 10' lubricator. Make up tools. (CTC 2.25" X .3') (XO 2.18" X .3') (DFCV 1.75" X 1.2') (STINGER 1.75" X 4') (JSN 1.75" X .58') TOL= 6.38'. Stab on well, pt low/high 250/4,000. Open well, Swab 22, T/I/O= 29/0/0. RIH. Come online with N2 1,000 scfm down the coil at 2,900'. WHP 0, IA 0, OA 0. Tag @ 4,162' CTMD. PU to 4,150', stop here for 15 min while pumping N2. Starting to get very minimal fluid returns to surface. Recipe up and down across 4,140'-4,150' up to the tbg tail @ 3,991' Made wiper trips up to 1,800' from TD. Manipulate N2 from rates from 500-1,000 scfm while staying parked above the perfs at 4,100'. Getting straight N2 back to tanks. POOH, Ran out of N2. Tagged up, swab shut, bleed down, pop off well. WHP 0, IA 0, OA 0. Recovered 50 bbls of 675 bbls injected. Job in progress. 12/27/2020 - Sunday CTU _____________________________________________________________________________________ Updated by DMA 01-08-21 SCHEMATIC Kenai Gas Field Well: KDU 02 Last Completed: 8/21/1968 PTD: 168-049 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor N/A Surf 58' 13-3/8' Surface 54.5 / J-55 / STC 12.615 Surf 1,317' 9-5/8" Intermediate 40 / N-80 / Seal Lock 8.835 Surf 6,027' 7" Liner 29 / N-80 / BTC 6.184 5,821’ 10,522' TUBING DETAIL 3-1/2" Tubing 9.2 / N-80 / Butt Mod 2.992 Surf 3,992’ JEWELRY DETAIL No Depth ID Item 1A 2,886’ 4.00” 4-1/2” x 9-5/8” DLH Packer (2/23/20) 1B 2,939’ 2.81” X-nipple (2/23/20) 1C 3,991’ 2.992” WLEG (2/23/20) 1D 4,175' Cement plug 12/17/20 (CTMD tag) 2A 4,370’ Posiset Plug 2B 5,007’ Cement Retainer 3 5,385’ Cement Retainer 4 5,921’ Cement Retainer 5 7,861’ Cement Retainer 6 9,325’ Cement Retainer 7 9,500’ Baker Packer 8 9,744’ Junk Retainer 9 9,750’ Cement Retainer 10 9,950’ Cement Retainer 11 10,436’ Junk Retainer 12 10,477’ Cement Retainer OPEN HOLE / CEMENT DETAIL 13-3/8" Cmt w/ 650 sks of class "G" 9-5/8" Cmt w/ 700 sks of class "G" through shoe& w/ 300 sks thru DV tool @1918' 7” Cmt w/ 1000 sks of class "G" PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Sterling A8 4,140’ 4,150’ 3,659’ 3,668’ 10 1/28/20 Open 4,141’ 4,146’ 3660 3664 5 12/23/20 Cemented Sterling B1 4,380' 4,420' 3,865' 3,900' 40 3/30/2016 Isolated Sterling Pool 6 5,119' 5,120' 4,538' 4,539' 1' 5/17/2013 Squeezed 5,128' 5,138' 4,546' 4,556' 10' 5/17/2013 Squeezed 5,170' 5,190' 4,586' 4,605' 20' 5/17/2013 Squeezed 5,235' 5,265' 4,648' 4,676' 30' 5/17/2013 Squeezed UT / 72-8 7,911' 7,951' 7,276' 7,280' 40 3/18/1996 Squeezed UT / 73-1 7,973' 7,992' 7,338' 7,357' 19 3/18/1996 Squeezed UT / 75-8 8,220' 8,262' 7,584' 7,626' 42 11/29/1995 Squeezed Upper Ty/Bel 8,245' 8,255' 7,609' 7,618' 10' Nov-95 Squeezed Tyonek 9,510' 9,522' 8,874' 8,886' 12' 8/13/1968 Isolated 9,558' 9,588' 8,922' 8,952' 30' 9,854' 9,874' 9,218' 9,238' 20' 8/4/1974 Squeezed / Isolated (8/8/1974) 9,884' 9,910' 9,248' 9,274' 26' 9,919' 9,920' 9,283' 9,284' 1' 10,006' 10,007' 9,370' 9,371' 1' 7/27/1974 10,028' 10,036' 9,392' 9,400' 8' 8/13/1968 10,080' 10,092' 9,443' 9,455' 12' 8/13/1968 S Ste Ste Ster U U U Upp T 4,141’4,146’3660 3664 5 12/23/20 Cemented Squeezed perfs reshot 4141-4146 ft.TOC 4175 ft. A11 4310-4350 is sqzd with cement. Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 01/14/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KDU-02 (168-049) DD-PERF PERFORATING RECORD 12/22/2020 Please include current contact information if different from above. 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WƵƐŚĨŝŶĞƐĨĂƌŽƵƚŝŶƚŽĨŽƌŵĂƚŝŽŶ;ΕϭϬ͛Ϳ ď͘ ^ƚĂďŝůŝǌĞĨŝŶĞƐ ƚŽƉƌĞǀĞŶƚĨƵƚƵƌĞŵŝŐƌĂƚŝŽŶ Đ͘ dƌĞĂƚŵĂƚƌŝǆƚŽƉƌĞǀĞŶƚ ĨƵƚƵƌĞ ĐůĂǇƐǁĞůůŝŶŐͬŵŽďŝůŝǌĂƚŝŽŶ Ě͘ dƌĞĂƚŵĞŶƚĞǆƉĞĐƚĞĚƚŽůĂƐƚϭϮͲϭϴŵŽŶƚŚƐ ϰ͘ WƌŽǀĞƵƉĐŚĞŵŝĐĂůƐƋƵĞĞǌĞĨŽƌƵƐĞŝŶŽƚŚĞƌƉĂƌƚƐŽĨƚŚĞĨŝĞůĚ EŽƚĞƐZĞŐĂƌĚŝŶŐtĞůůďŽƌĞŽŶĚŝƚŝŽŶ x DŝŶ/сϮ͘ϴϭ͟ ĂƚϮϵϯϵ͛D;ϯͲϭͬϮ͟ǆͲŶŝƉƉůĞͿ x ZtKD/dͲ/ ƉĂƐƐĞĚƚŽ ϮϬϬϬ ƉƐŝŽŶ ϮͬϮϰͬϮϬĂĨƚĞƌϯͲϭͬϮ͟ƚƵďŝŶŐ ĂŶĚƉĂĐŬĞƌ ŝŶƐƚĂůůĞĚ x DĂǆĚĞǀŝĂƚŝŽŶ͗ ϯϱ ĚĞŐƌĞĞƐ ĨƌŽŵϮϱϬϬ ʹ ϰϭϬϬ͛D x ĞǀŝĂƚŝŽŶĂĐƌŽƐƐĐĞŵĞŶƚŝŶŐŝŶƚĞƌǀĂů͗ϯϭĚĞŐƌĞĞƐ x >ĂƚĞƐƚĚƌŝĨƚͬƚĂŐ͗KŶ ϴͬϮϮͬϮϬ^> ƚĂŐŐĞĚĨŝůůĂƚϯϴϯϳ͛D͘EŽƉƌŽĚƵĐƚŝŽŶƐŝŶĐĞ͘ x DŽƐƚůŝŬĞůǇ Ͳϴ ƌĞƐĞƌǀŽŝƌW͗ ϱϬϬƉƐŝĂƚ ϰϭϰϱ͛ D;ϯϲϲϰ͛ dsͿ x &ƌĂĐƉƌĞƐƐƵƌĞ ĨŽƌͲϴƐĂŶĚ͗ ϭϴϳϱƉƐŝ ďŽƚƚŽŵŚŽůĞƉƌĞƐƐƵƌĞ Ăƚ ϰϭϰϱ͛ D;ϯϲϲϰ͛ dsͿ lay in cement plug with CT (with N2) tĞůůWƌŽŐŶŽƐŝƐ tĞůů͗ <hͲϬϮ ĂƚĞ͗ ϭϬͬϬϭͬϮϬϮϬ ZŝƐŬƐ ZŝƐŬ DŝƚŝŐĂƚŝŽŶͬŽŶƚŝŶŐĞŶĐǇ WƵŵƉŝŶŐŚĞŵŝĐĂůƐ &ŽůůŽǁǀĞŶĚŽƌƌĞĐŽŵŵĞŶĚĂƚŝŽŶƐŽŶWWĂŶĚƉƌŽĐĞĚƵƌĞ͘ZĞĂĚ D^^ĨŽƌĞĂĐŚƉƌŽĚƵĐƚ͘ WƵŵƉŝŶŐEŝƚƌŽŐĞŶ ,ŽůĚƉƌĞͲũŽďĂŶĚƌĞǀŝĞǁ^ƚĂŶĚĂƌĚEŝƚƌŽŐĞŶWƌŽĐĞĚƵƌĞ;ĂƚƚĂĐŚĞĚͿ ^ĂŶĚŝŶĨůŽǁĚƵƌŝŶŐ &K ZĞƐĞƌǀŽŝƌ ƉƌĞƐƐƵƌĞ ŽĨͲϴ ŝƐŵŽƐƚůŝŬĞůǇ ϱϬϬ ƉƐŝ ;ͲϭϭŝƐŚŝŐŚĞƌͿ͕ƐŽ ŚŽůĚŝŶŐĞǀĞŶĂůŝƚƚůĞďĂĐŬƉƌĞƐƐƵƌĞŽŶƌĞƚƵƌŶƐƚŚƌŽƵŐŚŽƵƚƚŚĞ ĐůĞĂŶŽƵƚƐŚŽƵůĚŽǀĞƌƉƌĞƐƐƵƌĞƚŚĞƌĞƐĞƌǀŽŝƌ͕ĂŶĚƐƚŽƉŝŶĨůŽǁ͘ ZĞǀŝĞǁDĂƌĐŚͲϮϬϮϬ&KĨŽƌůĞƐƐŽŶƐůĞĂƌŶĞĚ ;ŚĞůĚϯϱϬƉƐŝ ďĂĐŬƉƌĞƐƐƵƌĞ͕ĂŶĚŚĂĚƐƵĐĐĞƐƐͿ >ŽƐĞƌĞƚƵƌŶƐĚƵƌŝŶŐ&KĂŶĚĞŶĚ ƵƉƉƵƐŚŝŶŐƐĂŶĚĂǁĂǇ K<ƐĐĞŶĂƌŝŽ͕ũƵƐƚǁŽƵůĚŶĞĞĚƚŽƚƌĂƉƐŽŵĞ ƐŚƵƚͲŝŶ t,WǁŚĞŶ ĚŽŶĞǁŝƚŚ&KƚŽƉƌĞǀĞŶƚŝƚĨůŽǁŝŶŐďĂĐŬ͘ tŽƌŬŝŶŐĨůƵŝĚĚĂŵĂŐŝŶŐŵĂƚƌŝǆ hƐĞĐůĞĂŶĂŶĚĨŝůƚĞƌĞĚǁĂƚĞƌ ǁŝƚŚĂ <>ĐŽŶĐĞŶƚƌĂƚŝŽŶŽĨ ϲйŽƌ ŐƌĞĂƚĞƌƚŚƌŽƵŐŚŽƵƚũŽď͘ tĂŶƚƚŽŬĞĞƉƉƵŵƉƌĂƚĞƐďĞůŽǁ ĨƌĂĐƉƌĞƐƐƵƌĞĚƵƌŝŶŐƐƋƵĞĞǌĞ dƌǇƚŽŬĞĞƉĞƐƚŝŵĂƚĞĚ,WďĞůŽǁ ĨƌĂĐƉƌĞƐƐƵƌĞĚƵƌŝŶŐ ĐŚĞŵŝĐĂů ƐƋƵĞĞǌĞ͘/ĨĨŽƌŵĂƚŝŽŶƉƌĞƐƐƵƌĞƐƵƉ͕ƚƌǇƉƵŵƉĂŶĚǁĂŝƚŵĞƚŚŽĚ ƚŽƐůŽǁůǇƐƋƵĞĞǌĞĂǁĂǇ͘ ŽŝůĞĚdƵďŝŶŐ ^ƵŶĚƌǇƐƚĞƉƐ ϭ͘ D/Zh dhhŶŝƚ͘ WƌĞƐƐƵƌĞƚĞƐƚKWƐƚŽϮϱϬƉƐŝůŽǁͬ ϰ͕ϱϬϬƉƐŝŚŝŐŚ͘ Ϯ͘ Z/, ǁŝƚŚ ĂƐůŝĐŬ,ĨŽƌĐůĞĂŶŽƵƚĂŶĚĞƐƚĂďůŝƐŚƚĂŐĚĞƉƚŚ͘ ϯ͘ WĞƌĨŽƌŵĨŝůůĐůĞĂŶŽƵƚƚŽƚĂŶŬƐ ĚŽǁŶƚŽ ΕϰϮϳϱ͛D ĂͿ DŝŶŝŵƵŵĐůĞĂŶŽƵƚĚĞƉƚŚŶĞĞĚĞĚŝƐƚŽΕϰϮϬϬ͛ ďͿ tŽƌŬŝŶŐĨůƵŝĚƐŚŽƵůĚ ďĞĂƚ ůĞĂƐƚϲй<> ĐͿ >ŝŬĞůǇƚŽŶĞĞĚŶŝƚƌŽŐĞŶͬĨŽĂŵŽŶĐĞ ƚŽƉƉĞƌĨƐĂƌĞƵŶĐŽǀĞƌĞĚ ;ƐĞĞDĂƌͲϮϬϮϬ&KƌĞƉŽƌƚƐͿ ĚͿ ts ƚŽ ϰϯϱϱ͛ ŝƐΕϭϯϱ ďďůƐ ŝ͘ dƵďŝŶŐǀŽůƵŵĞ͗ϯϱ ďďůƐ ŝŝ͘ sŽůƵŵĞďĞŚŝŶĚ dd͗ ϳϬ ďďůƐ ŝŝŝ͘ ϵͲϱͬϴ͟ĐĂƐŝŶŐǀŽůƵŵĞďĞůŽǁdd͗ϮϴďďůƐ ϭ͘ ŽƚƚŽŵͲϬϴ ƉĞƌĨƚŽdd͗ϭϱϴ͛ͬϭϮďďůƐ Ϯ͘ dŽƉͲϭϭƉĞƌĨƚŽďŽƚƚŽŵͲϴƉĞƌĨ͗ϭϲϬ͛ͬϭϮďďůƐ ϯ͘ dKŽŶ WŽƐƐŝƐĞƚ ƚŽƚŽƉͲϭϭƉĞƌĨ͗ϰϱ͛ͬϯ͘ϰďďůƐ ĞͿ ŽĐƵŵĞŶƚĂůůƉƵŵƉĞĚĂŶĚƌĞĐŽǀĞƌĞĚǀŽůƵŵĞƐ ϰ͘ WKK, ĐŚĂƐŝŶŐĨŝůůƵƉŚŽůĞ ϱ͘ DhĐĞŵĞŶƚŝŶŐ,͕ĂŶĚZ/, ĨŽƌĚƌǇƚĂŐ ĂͿ ƐůŽŶŐĂƐĚƌǇƚĂŐŝƐĂƚϰϮϬϬ͛DŽƌĚĞĞƉĞƌƉƌŽĐĞĞĚǁŝƚŚĐĞŵĞŶƚƉůƵŐ ďͿ /ĨŚŝŐŚĞƌƚŚĂŶϰϮϬϬ͛ƌĞƐƵŵĞ&K͘ŽƵůĚďĞƐĞƚƚůĞĚƐŽůŝĚƐ͕Žƌ ŝĨŝŶĨůŽǁŝƐĞǆƉĞĐƚĞĚ͕ƉůĂǇǁŝƚŚ ƚƌĂƉƉŝŶŐƉƌĞƐƐƵƌĞŝŶƚŚĞǁĞůůďŽƌĞƚŽŚŽůĚŝƚďĂĐŬ ϲ͘ >ĂǇŝŶĐĞŵĞŶƚ ƚĂŬŝŶŐƌĞƚƵƌŶƐƚŽͲϴƐĂŶĚƚĂƌŐĞƚŝŶŐdŽĂƚ ϰϮϬϬ͛D ƚŽŝƐŽůĂƚĞͲϭϭƉĞƌĨƐ ĂͿ sŽůƵŵĞǁŝůůŶĞĞĚƚŽďĞĂĚũƵƐƚĞĚďĂƐĞĚŽŶŚŽǁĚĞĞƉ&KŵĂŬĞƐŝ ƚ ďͿ /ĚĞĂůůǇůĞĂǀĞĂŶƵŶĐĞŵĞŶƚĞĚ ϱϬ͛ƌĂƚŚŽůĞďĞůŽǁĚĞĞƉĞƐƚͲϴƉĞƌĨƐ ĐͿ DŝŶŝŵƵŵĐĞŵĞŶƚĨŽŽƚĂŐĞǁĂŶƚĞĚсϯϬ͛ ĚͿ dĂŬĞĐĞŵĞŶƚƐĂŵƉůĞĂƚƐƵƌĨĂĐĞƚŽŵŽŶŝƚŽƌĨŽƌƚŚŝĐŬĞŶŝŶŐ ϳ͘ WKK,ĂŶĚůĂǇĚŽǁŶĐĞŵĞŶƚŝŶŐĂƐƐĞŵďůǇ͘ ϴ͘ tŽƉĞƌǀĞŶĚŽƌƌĞĐŽŵŵĞŶĚĂƚŝŽŶ ϵ͘ WhĂŶĚZ/,ǁŝƚŚŶŽǌǌůĞĨŽƌĐŝƌĐ͛ŝŶŐĂŶĚĐŚĞŵŝĐĂůƐƋƵĞĞǌĞƚƌĞĂƚŵĞŶƚ ϭϬ͘ ƌǇƚĂŐdŽƚŽĞŶƐƵƌĞďĞůŽǁďŽƚƚŽŵͲϴƉĞƌĨĂƚ ϰϭϱϬ͛D ϭϭ͘ ƐůŽŶŐĂƐĐĞŵĞŶƚŚĂƐŚĂƌĚĞŶĞĚ͕ƉƌŽĐĞĞĚƚŽƉĞƌĨŽƌŵĂŶŝŶũĞĐƚŝǀŝƚǇƚĞƐƚǁŝƚŚ ϲй<>ďĞĨŽƌĞ ĐŚĞŵŝĐĂůŝƐůŽĂĚĞĚŝŶƚŽd Cement plug over A11 FCO with N2 CT FCO 4000 psi tĞůůWƌŽŐŶŽƐŝƐ tĞůů͗ <hͲϬϮ ĂƚĞ͗ ϭϬͬϬϭͬϮϬϮϬ ĂͿ ^ƚĂƌƚĂƚϭϬϬƉƐŝdƉƌĞƐƐƵƌĞ͕ ďͿ /ĨƌĂƚĞŝƐŝŶƐƵĨĨŝĐŝĞŶƚ;фϬ͘ϱďƉŵͿ͕ ĂƚƚĞŵƉƚŝŶũĞĐƚŝŽŶĂƚ ϮϬϬƉƐŝdƉƌĞƐƐƵƌĞ ĐͿ /ĨƐƚŝůůŝŶƐƵĨĨŝĐŝĞŶƚ ŝŶũĞĐƚŝǀŝƚǇ͕ĐŽŶƚĂĐƚKƚŽĚŝƐĐƵƐƐ ϭϮ͘ ŶƐƵƌĞ ǁŽƌŬŝŶŐĨůƵŝĚŝƐƐƚŝůůϲй<>͕ ĂŶĚ ƉƌŽĐĞĞĚƚŽĨŝŶĞƐ ƐƚĂďŝůŝǌĂƚŝŽŶƐƋƵĞĞǌĞ ƉĞƌ ǀĞŶĚŽƌ ƚƌĞĂƚŵĞŶƚƐĐŚĞĚƵůĞ ;ΕϭϳϬďďůƐƚŽďĞƐƋƵĞĞǌĞĚͿ͘ ĂͿ WůĂĐĞ,ĂƚŵŝĚƉĞƌĨĚƵƌŝŶŐƚƌĞĂƚŵĞŶƚ͘ ďͿ ,ŽůĚW:^DǁŝƚŚĂŬĞƌŚĂŶĚƐ͕ĂŶĚĚŝƐĐƵƐƐƌŝƐŬƐǁŝƚŚĐŚĞŵŝĐĂůƐ͕ĂŶĚũŽďůŽŐŝƐƚŝĐƐ͘ZĞĨĞƌƚŽ D^^ ĐͿ ƚƚĞŵƉƚƚŽŬĞĞƉ ƚƌĞĂƚŝŶŐƉƌĞƐƐƵƌĞƐďĞůŽǁĨƌĂĐƚƵƌĞƉƌĞƐƐƵƌĞĂƚ, ĚͿ EŽƌĂƚĞůŝŵŝƚĚƵƌŝŶŐũŽď͕ŵĂǇǀĞƌǇǁĞůůƚĂŬĞƚƌĞĂƚŵĞŶƚũƵƐƚĨƌŽŵŚǇĚƌŽƐƚĂƚŝĐĨŽƌĐĞƐ͘KŬŝĨ ƐŽ͕ũƵƐƚŵŽŶŝƚŽƌǀŽůƵŵĞƐ ϭϯ͘ ůůŽǁƚƌĞĂƚŵĞŶƚƚŽƐŽĂŬĨŽƌĂƚůĞĂƐƚϴ ŚƌƐ͘ ĂĨƚĞƌ ƚŚĞƚƌĞĂƚŵĞŶƚŝƐĐŽŵƉůĞƚĞ͘ ϭϰ͘ hŶůŽĂĚƚƵďŝŶŐǁŝƚŚ EϮĨůŽǁŝŶŐƚŽƉƌŽĚƵĐƚŝŽŶ͘ ĂͿ ZĞǀŝĞǁ^ƚĂŶĚĂƌĚEŝƚƌŽŐĞŶWƌŽĐĞĚƵƌĞ͕ĂŶĚƚĂŬĞĐĂƵƚŝŽŶǁŚŝůĞƵƐŝŶŐŝƚ͘ ďͿ DĂŬĞƐƵƌĞǁĞĂƌĞƌĞĐŽƌĚŝŶŐĐƵŵƵůĂƚŝǀĞǁĂƚĞƌǀŽůƵŵĞƐƌĞĐŽǀĞƌĞĚ ĐͿ tsΕϭϮϱďďůƐ ϭϱ͘ /ĨĂĨƚĞƌĂĨƵůůEϮďůŽǁĚŽǁŶǁŝƚŚd͕ǁĞůůƐƚŝůůŝƐŶ͛ƚĨůŽǁŝŶ Ő͕ƚƌĂƉΕϮϬϬ ƉƐŝŶŝƚƌŽŐĞŶƉƌĞƐƐƵƌĞŽŶǁĞůů ĂŶĚƉƌŽĐĞĞĚƚŽďĞůŽǁ>ƌĞƉĞƌĨƉƌŽĐĞĚƵƌĞ ŽŶƚŝŶŐĞŶƚ>ZĞƉĞƌĨ ϭϲ͘ D/Zh ͲůŝŶĞ ĂŶĚƉƌĞƐƐƵƌĞĐŽŶƚƌŽůĞƋƵŝƉŵĞŶƚ͘WdůƵďƌŝĐĂƚŽƌƚŽϮϱϬƉƐŝůŽǁͬϮ͕ϱϬϬƉƐŝŚŝŐŚ ϭϳ͘ Z/,tͬ'WdƚŽŽůĂŶĚĨŝŶĚĨůƵŝĚůĞǀĞů͘ŽŶƐƵůƚǁŝƚŚKƚŽƐĞ ĞŝĨǁĞŶĞĞĚƚŽƉƌŽĐĞĞĚƚŽŶŝƚƌŽŐĞŶ ĚŝƐƉůĂĐĞŵĞŶƚ͕ŽƌƐŚŽŽƚĂƐͲŝƐ͘ ϭϴ͘ ZŝŐƵƉƉĞƌĨŐƵŶƐĂŶĚZ/, ϭϵ͘ WĞƌĨŽƌĂƚĞƚŚĞ ƐĂŶĚ ůŝƐƚĞĚŝŶƚŚĞƚĂďůĞďĞůŽǁ͘ ^ĂŶĚ dŽƉ ;DͿ ŽƚƚŽŵ ;DͿ dŽƉ;dsͿ ŽƚƚŽŵ ;dsͿ >ĞŶŐƚŚ ;Ĩƚ͘Ϳ Ͳϴ цϰϭϰϬ͛цϰϭϱϬ͛цϯϲϱϵ͛цϯϲϲϴ͛ϭϬ Ă͘ ůĞĞĚt,WĚŽǁŶƉĞƌK͘ E &RUUHODWHXVLQJ2SHQ+ROH&RUUHODWLRQ/RJSURYLGHGE\*HRORJL VW6HQGWKHFRUUHODWLRQSDVV WRWKH2SHUDWLRQV(QJLQHHU5HVHUYRLU(QJLQHHUDQG*HRORJLVWIRUFRQILUPDWLRQ c. Use Gamma/CCL to correlate. G ,QVWDOO&U\VWDOJDXJHVRUYHULI\37VDUHRSHQWR6&$'$ EHIRUHSHUIRUDWLQJ5HFRUGWXELQJ SUHVVXUHVEHIRUHDQGDIWHUHDFKSHUIRUDWLQJUXQ H 5HFRUGDQGPLQXWHWXELQJSUHVVXUHVDIWHUILULQJ ϮϬ͘ WKK,͕ZͲůŝŶĞ͘ Ϯϭ͘ dƵƌŶǁĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶ͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ĐƚƵĂů ^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘ ^ƚĂŶĚĂƌĚ EŝƚƌŽŐĞŶƉƌŽĐĞĚƵƌĞ REPERF chemical sqz BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚďǇ ZZϬϵͲϯϬͲϮϬ ^,Dd/ <ĞŶĂŝ'ĂƐ &ŝĞůĚ tĞůů͗<hϬϮ >ĂƐƚ ŽŵƉůĞƚĞĚ͗ϴͬϮϭͬϭϵϲϴ Wd͗ ϭϲϴͲϬϰϵ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ /dŽƉ ƚŵ ϮϬΗ ŽŶĚƵĐƚŽƌ Eͬ^ƵƌĨ ϱϴΖ ϭϯͲϯͬϴΖ ^ƵƌĨĂĐĞ ϱϰ͘ϱͬ:Ͳϱϱ ͬ^dϭϮ͘ϲϭϱ ^ƵƌĨ ϭ͕ϯϭϳΖ ϵͲϱͬϴΗ /ŶƚĞƌŵĞĚŝĂƚĞ ϰϬͬEͲϴϬ ͬ^ĞĂů>ŽĐŬ ϴ͘ϴϯϱ ^ƵƌĨ ϲ͕ϬϮϳΖ ϳΗ >ŝŶĞƌ ϮϵͬEͲϴϬͬdϲ͘ϭϴϰ ϱ͕ϴϮϭ͛ϭϬ͕ϱϮϮΖ dh/E'd/> ϯͲϭͬϮΗ dƵďŝŶŐ ϵ͘ϮͬEͲϴϬͬƵƚƚDŽĚ Ϯ͘ϵϵϮ ^ƵƌĨ ϯ͕ϵϵϮ͛ :t>Zzd/> EŽ ĞƉƚŚ //ƚĞŵ ϭϮ͕ϴϴϲ͛ϰ͘ϬϬ͟ϰͲϭͬϮ͟ǆϵͲϱͬϴ͟>, WĂĐŬĞƌ ;ϮͬϮϯͬϮϬͿ ϭϮ͕ϵϯϵ͛Ϯ͘ϴϭ͟yͲŶŝƉƉůĞ;ϮͬϮϯͬϮϬͿ ϭϯ͕ϵϵϭ͛Ϯ͘ϵϵϮ͟t>';ϮͬϮϯͬϮϬͿ Ϯϰ͕ϯϳϬ͛WŽƐŝƐĞƚWůƵŐ Ϯϱ͕ϬϬϳ͛ĞŵĞŶƚZĞƚĂŝŶĞƌ ϯ ϱ͕ϯϴϱ͛ĞŵĞŶƚZĞƚĂŝŶĞƌ ϰ ϱ͕ϵϮϭ͛ĞŵĞŶƚZĞƚĂŝŶĞƌ ϱ ϳ͕ϴϲϭ͛ĞŵĞŶƚZĞƚĂŝŶĞƌ ϲ ϵ͕ϯϮϱ͛ĞŵĞŶƚZĞƚĂŝŶĞƌ ϳ ϵ͕ϱϬϬ͛ĂŬĞƌWĂĐŬĞƌ ϴ ϵ͕ϳϰϰ͛:ƵŶŬZĞƚĂŝŶĞƌ ϵ ϵ͕ϳϱϬ͛ĞŵĞŶƚZĞƚĂŝŶĞƌ ϭϬ ϵ͕ϵϱϬ͛ĞŵĞŶƚZĞƚĂŝŶĞƌ ϭϭ ϭϬ͕ϰϯϲ͛:ƵŶŬZĞƚĂŝŶĞƌ ϭϮ ϭϬ͕ϰϳϳ͛ĞŵĞŶƚZĞƚĂŝŶĞƌ KWE,K>ͬDEdd/> ϭϯͲϯͬϴΗ ŵƚǁͬϲϱϬƐŬƐŽĨĐůĂƐƐΗ'Η ϵͲϱͬϴΗ ŵƚǁͬϳϬϬƐŬƐŽĨĐůĂƐƐΗ'ΗƚŚƌŽƵŐŚƐŚŽĞΘǁͬϯϬϬƐŬƐƚŚƌƵsƚŽŽůΛϭϵϭϴΖ ϳ͟ŵƚǁͬϭϬϬϬƐŬƐŽĨĐůĂƐƐΗ'Η d/sWZ&KZd/KEd/> ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ ;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ ^ƚĞƌůŝŶŐϴ ϰ͕ϭϰϬ͛ϰ͕ϭϱϬ͛ϯ͕ϲϱϵ͛ϯ͕ϲϲϴ͛ϭϬ ϭͬϮϴͬϮϬϮϬ KƉĞŶ ^ƚĞƌůŝŶŐϭϭ ϰ͕ϯϭϬΖ ϰ͕ϯϱϬΖ ϯ͕ϴϬϰΖ ϯ͕ϴϯϵΖ ϰϬ ϰͬϮϴͬϮϬϭϲ KƉĞŶ /^K>dWZ&KZd/KEd/> ^ƚĞƌůŝŶŐϭ ϰ͕ϯϴϬΖ ϰ͕ϰϮϬΖ ϯ͕ϴϲϱΖ ϯ͕ϵϬϬΖ ϰϬ ϯͬϯϬͬϮϬϭϲ /ƐŽůĂƚĞĚ ^ƚĞƌůŝŶŐWŽŽůϲ ϱ͕ϭϭϵΖ ϱ͕ϭϮϬΖ ϰ͕ϱϯϴΖ ϰ͕ϱϯϵΖ ϭΖ ϱͬϭϳͬϮϬϭϯ ^ƋƵĞĞǌĞĚ ϱ͕ϭϮϴΖ ϱ͕ϭϯϴΖ ϰ͕ϱϰϲΖ ϰ͕ϱϱϲΖ ϭϬΖ ϱͬϭϳͬϮϬϭϯ ^ƋƵĞĞǌĞĚ ϱ͕ϭϳϬΖ ϱ͕ϭϵϬΖ ϰ͕ϱϴϲΖ ϰ͕ϲϬϱΖ ϮϬΖ ϱͬϭϳͬϮϬϭϯ ^ƋƵĞĞǌĞĚ ϱ͕ϮϯϱΖ ϱ͕ϮϲϱΖ ϰ͕ϲϰϴΖ ϰ͕ϲϳϲΖ ϯϬΖ ϱͬϭϳͬϮϬϭϯ ^ƋƵĞĞǌĞĚ hdͬϳϮͲϴ ϳ͕ϵϭϭΖ ϳ͕ϵϱϭΖ ϳ͕ϮϳϲΖ ϳ͕ϮϴϬΖ ϰϬ ϯͬϭϴͬϭϵϵϲ ^ƋƵĞĞǌĞĚ hdͬϳϯͲϭ ϳ͕ϵϳϯΖ ϳ͕ϵϵϮΖ ϳ͕ϯϯϴΖ ϳ͕ϯϱϳΖ ϭϵ ϯͬϭϴͬϭϵϵϲ ^ƋƵĞĞǌĞĚ hdͬϳϱͲϴ ϴ͕ϮϮϬΖ ϴ͕ϮϲϮΖ ϳ͕ϱϴϰΖ ϳ͕ϲϮϲΖ ϰϮ ϭϭͬϮϵͬϭϵϵϱ ^ƋƵĞĞǌĞĚ hƉƉĞƌdǇͬĞů ϴ͕ϮϰϱΖ ϴ͕ϮϱϱΖ ϳ͕ϲϬϵΖ ϳ͕ϲϭϴΖ ϭϬΖ EŽǀͲϵϱ ^ƋƵĞĞǌĞĚ dǇŽŶĞŬ ϵ͕ϱϭϬΖ ϵ͕ϱϮϮΖ ϴ͕ϴϳϰΖ ϴ͕ϴϴϲΖ ϭϮΖ ϴͬϭϯͬϭϵϲϴ /ƐŽůĂƚĞĚϵ͕ϱϱϴΖ ϵ͕ϱϴϴΖ ϴ͕ϵϮϮΖ ϴ͕ϵϱϮΖ ϯϬΖ ϵ͕ϴϱϰΖ ϵ͕ϴϳϰΖ ϵ͕ϮϭϴΖ ϵ͕ϮϯϴΖ ϮϬΖ ϴͬϰͬϭϵϳϰ ^ƋƵĞĞǌĞĚͬ /ƐŽůĂƚĞĚ ;ϴͬϴͬϭϵϳϰͿ ϵ͕ϴϴϰΖ ϵ͕ϵϭϬΖ ϵ͕ϮϰϴΖ ϵ͕ϮϳϰΖ ϮϲΖ ϵ͕ϵϭϵΖ ϵ͕ϵϮϬΖ ϵ͕ϮϴϯΖ ϵ͕ϮϴϰΖ ϭΖ ϭϬ͕ϬϬϲΖ ϭϬ͕ϬϬϳΖ ϵ͕ϯϳϬΖ ϵ͕ϯϳϭΖ ϭΖ ϳͬϮϳͬϭϵϳϰ ϭϬ͕ϬϮϴΖ ϭϬ͕ϬϯϲΖ ϵ͕ϯϵϮΖ ϵ͕ϰϬϬΖ ϴΖ ϴͬϭϯͬϭϵϲϴ ϭϬ͕ϬϴϬΖ ϭϬ͕ϬϵϮΖ ϵ͕ϰϰϯΖ ϵ͕ϰϱϱΖ ϭϮΖ ϴͬϭϯͬϭϵϲϴ 6027' BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚďǇ ZZϵͲϯϬͲϮϬ WZKWK^ ^,Dd/ <ĞŶĂŝ'ĂƐ &ŝĞůĚ tĞůů͗<hϬϮ >ĂƐƚ ŽŵƉůĞƚĞĚ͗ϴͬϮϭͬϭϵϲϴ Wd͗ ϭϲϴͲϬϰϵ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ /dŽƉ ƚŵ ϮϬΗ ŽŶĚƵĐƚŽƌ Eͬ^ƵƌĨ ϱϴΖ ϭϯͲϯͬϴΖ ^ƵƌĨĂĐĞ ϱϰ͘ϱͬ:Ͳϱϱ ͬ^dϭϮ͘ϲϭϱ ^ƵƌĨ ϭ͕ϯϭϳΖ ϵͲϱͬϴΗ /ŶƚĞƌŵĞĚŝĂƚĞ ϰϬͬEͲϴϬ ͬ^ĞĂů>ŽĐŬ ϴ͘ϴϯϱ ^ƵƌĨ ϲ͕ϬϮϳΖ ϳΗ >ŝŶĞƌ ϮϵͬEͲϴϬͬdϲ͘ϭϴϰ ϱ͕ϴϮϭ͛ϭϬ͕ϱϮϮΖ dh/E'd/> ϯͲϭͬϮΗ dƵďŝŶŐ ϵ͘ϮͬEͲϴϬͬƵƚƚDŽĚ Ϯ͘ϵϵϮ ^ƵƌĨ ϯ͕ϵϵϮ͛ :t>Zzd/> EŽ ĞƉƚŚ //ƚĞŵ ϭϮ͕ϴϴϲ͛ϰ͘ϬϬ͟ϰͲϭͬϮ͟ǆϵͲϱͬϴ͟>, WĂĐŬĞƌ ;ϮͬϮϯͬϮϬͿ ϭϮ͕ϵϯϵ͛Ϯ͘ϴϭ͟yͲŶŝƉƉůĞ;ϮͬϮϯͬϮϬͿ ϭϯ͕ϵϵϭ͛Ϯ͘ϵϵϮ͟t>';ϮͬϮϯͬϮϬͿ ϭϰϮϬϬ͛ĞŵĞŶƚƉůƵŐ Ϯϰ͕ϯϳϬ͛WŽƐŝƐĞƚWůƵŐ Ϯϱ͕ϬϬϳ͛ĞŵĞŶƚZĞƚĂŝŶĞƌ ϯ ϱ͕ϯϴϱ͛ĞŵĞŶƚZĞƚĂŝŶĞƌ ϰ ϱ͕ϵϮϭ͛ĞŵĞŶƚZĞƚĂŝŶĞƌ ϱ ϳ͕ϴϲϭ͛ĞŵĞŶƚZĞƚĂŝŶĞƌ ϲ ϵ͕ϯϮϱ͛ĞŵĞŶƚZĞƚĂŝŶĞƌ ϳ ϵ͕ϱϬϬ͛ĂŬĞƌWĂĐŬĞƌ ϴ ϵ͕ϳϰϰ͛:ƵŶŬZĞƚĂŝŶĞƌ ϵ ϵ͕ϳϱϬ͛ĞŵĞŶƚZĞƚĂŝŶĞƌ ϭϬ ϵ͕ϵϱϬ͛ĞŵĞŶƚZĞƚĂŝŶĞƌ ϭϭ ϭϬ͕ϰϯϲ͛:ƵŶŬZĞƚĂŝŶĞƌ ϭϮ ϭϬ͕ϰϳϳ͛ĞŵĞŶƚZĞƚĂŝŶĞƌ KWE,K>ͬDEdd/> ϭϯͲϯͬϴΗ ŵƚǁͬϲϱϬƐŬƐŽĨĐůĂƐƐΗ'Η ϵͲϱͬϴΗ ŵƚǁͬϳϬϬƐŬƐŽĨĐůĂƐƐΗ'ΗƚŚƌŽƵŐŚƐŚŽĞΘǁͬϯϬϬƐŬƐƚŚƌƵsƚŽŽůΛϭϵϭϴΖ ϳ͟ŵƚǁͬϭϬϬϬƐŬƐŽĨĐůĂƐƐΗ'Η d/sWZ&KZd/KEd/> ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ ;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ ^ƚĞƌůŝŶŐϴ ϰ͕ϭϰϬ͛ϰ͕ϭϱϬ͛ϯ͕ϲϱϵ͛ϯ͕ϲϲϴ͛ϭϬ ϭͬϮϴͬϮϬϮϬ KƉĞŶ ^ƚĞƌůŝŶŐϭϭ ϰ͕ϯϭϬΖ ϰ͕ϯϱϬΖ ϯ͕ϴϬϰΖ ϯ͕ϴϯϵΖ ϰϬ ϰͬϮϴͬϮϬϭϲ dŽďĞ /ƐŽůĂƚĞĚ /^K>dWZ&KZd/KEd/> ^ƚĞƌůŝŶŐϭ ϰ͕ϯϴϬΖ ϰ͕ϰϮϬΖ ϯ͕ϴϲϱΖ ϯ͕ϵϬϬΖ ϰϬ ϯͬϯϬͬϮϬϭϲ /ƐŽůĂƚĞĚ ^ƚĞƌůŝŶŐWŽŽůϲ ϱ͕ϭϭϵΖ ϱ͕ϭϮϬΖ ϰ͕ϱϯϴΖ ϰ͕ϱϯϵΖ ϭΖ ϱͬϭϳͬϮϬϭϯ ^ƋƵĞĞǌĞĚ ϱ͕ϭϮϴΖ ϱ͕ϭϯϴΖ ϰ͕ϱϰϲΖ ϰ͕ϱϱϲΖ ϭϬΖ ϱͬϭϳͬϮϬϭϯ ^ƋƵĞĞǌĞĚ ϱ͕ϭϳϬΖ ϱ͕ϭϵϬΖ ϰ͕ϱϴϲΖ ϰ͕ϲϬϱΖ ϮϬΖ ϱͬϭϳͬϮϬϭϯ ^ƋƵĞĞǌĞĚ ϱ͕ϮϯϱΖ ϱ͕ϮϲϱΖ ϰ͕ϲϰϴΖ ϰ͕ϲϳϲΖ ϯϬΖ ϱͬϭϳͬϮϬϭϯ ^ƋƵĞĞǌĞĚ hdͬϳϮͲϴ ϳ͕ϵϭϭΖ ϳ͕ϵϱϭΖ ϳ͕ϮϳϲΖ ϳ͕ϮϴϬΖ ϰϬ ϯͬϭϴͬϭϵϵϲ ^ƋƵĞĞǌĞĚ hdͬϳϯͲϭ ϳ͕ϵϳϯΖ ϳ͕ϵϵϮΖ ϳ͕ϯϯϴΖ ϳ͕ϯϱϳΖ ϭϵ ϯͬϭϴͬϭϵϵϲ ^ƋƵĞĞǌĞĚ hdͬϳϱͲϴ ϴ͕ϮϮϬΖ ϴ͕ϮϲϮΖ ϳ͕ϱϴϰΖ ϳ͕ϲϮϲΖ ϰϮ ϭϭͬϮϵͬϭϵϵϱ ^ƋƵĞĞǌĞĚ hƉƉĞƌdǇͬĞů ϴ͕ϮϰϱΖ ϴ͕ϮϱϱΖ ϳ͕ϲϬϵΖ ϳ͕ϲϭϴΖ ϭϬΖ 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WƵŵƉ ŶŝƚƌŽŐĞŶĂƚĚĞƐŝƌĞĚƌĂƚĞ͕ŵŽŶŝƚŽƌŝŶŐƌĂƚĞ;^&DͿĂŶĚƉƌĞƐƐƵƌĞ;W^/Ϳ͘ůůŶŝƚƌŽŐĞŶƌĞƚƵƌŶƐ ĂƌĞƚŽďĞƌŽƵƚĞĚƚŽƚŚĞƌĞƚƵƌŶƐƚĂŶŬ͘ ϭϱ͘Ϳ tŚĞŶ ĨŝŶĂůŶŝƚƌŽŐĞŶǀŽůƵŵĞŚĂƐďĞĞŶĂĐŚŝĞǀĞĚ͕ŝƐŽůĂƚĞǁĞůůĨƌŽŵ EŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚ ĂŶĚ ďůĞĞĚĚŽǁŶůŝŶĞƐďĞƚǁĞĞŶǁĞůůĂŶĚ EŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚ͘ ϭϲ͘Ϳ KŶĐĞ ǇŽƵŚĂǀĞĐŽŶĨŝƌŵĞĚůŝŶĞƐĂƌĞďůĞĚĚŽǁŶ͕ŶŽƚƌĂƉƉĞĚƉƌĞƐƐƵƌĞĞǆŝƐƚƐ͕ĂŶĚŶŽŶŝƚƌŽŐĞŶŚĂƐ ĂĐĐƵŵƵůĂƚĞĚďĞŐŝŶ ƌŝŐĚŽǁŶŽĨůŝŶĞƐĨƌŽŵƚŚĞEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚ͘ ϭϳ͘Ϳ &ŝŶĂůŝǌĞ ũŽďůŽŐĂŶĚĚŝƐĐƵƐƐŽƉĞƌĂƚŝŽŶƐǁŝƚŚtĞůůƐŝƚĞ DĂŶĂŐĞƌ͘ŽĐƵŵĞŶƚĂŶǇůĞƐƐŽŶƐůĞĂƌŶĞĚ ĂŶĚĐŽŶĨŝƌŵĨŝŶĂůƌĂƚĞƐͬƉƌĞƐƐƵƌĞͬǀŽůƵŵĞƐŽĨƚŚĞũŽďĂŶĚƌĞŵĂŝŶŝŶŐŶŝƚƌŽŐĞŶŝŶƚŚĞƚƌĂŶƐƉŽƌƚ͘ ϭϴ͘Ϳ ZDK EŝƚƌŽŐĞŶWƵŵƉŝŶŐ hŶŝƚĂŶĚ>ŝƋƵŝĚEŝƚƌŽŐĞŶdƌĂŶƐƉŽƌƚ͘ Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 09/29/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KGF KDU-02 (168-049) PERFORATING RECORD 01/28/2020 Please include current contact information if different from above. Received by the AOGCC 09/29/2020 PTD: 1680490 E-Set: 34007 Abby Bell 09/29/2020 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Run Pkr Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: FCO/ Displace, N2 Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10,522 feet 4,866 feet true vertical 9,885 feet N/A feet Effective Depth measured 4,355 feet N/A feet true vertical 3,843 feet N/A feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)3-1/2" 9.2#/N-80 2,085' MD 1,955' TVD Packers and SSSV (type, measured and true vertical depth)N/A; N/A N/A; N/A N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 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 Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Ted Kramer Authorized Title:Operations Manager Contact Email: Contact Phone:777-8420 tkramer@hilcorp.com Senior Engineer:Senior Res. Engineer: 8,160psi Burst 58' 1,295' 5,412'5,750psi 2,730psi Collapse 1,130psi 3,090psi 7,020psi Casing Structural 20" 13-3/8" 9-5/8" Length 58' 1,317' 6,027' Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: 850 Casing Pressure Liner 4,701' 1,869 9,885' 0 Representative Daily Average Production or Injection Data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-070 193 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 185 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 168-049 50-133-20121-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 1460 Kenai Deep Unit (KDU) 2(21-8) N/A FEDA028142 6,027' Plugs Junk measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Kenai Gas Field / Sterling 3 GasN/A measured TVD Tubing PressureOil-Bbl measured true vertical Packer 7" WINJ WAG 2,796 Water-Bbl MD 58' 1,317' 10,522' 111 t Fra O Run 6. A G L PG , R 2 Form 10-404 Revised 3/2020 Submit Within 30 days of Operations Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.04.16 14:08:59 -08'00' Taylor Wellman By Samantha Carlisle at 2:44 pm, Apr 16, 2020 DSR-4/16/2020gls 4/17/20 RBDMS HEW 4/16/2020 Rig Start Date End Date 2/17/20 3/31/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KDU-02 50-133-20541-00 204-107 02/18/2020 - Tuesday Continue rigging up on KDU-2: Complete berm around rig. Adjust base beam, set choke house and accumulator unit. Install landings, derrick dog house and new SRL for derrick climber. Spot carrier over well, set pits, Dragon Fire heater and mud pump units. Move bang board, grease crown and rig up gas buster. Raise mast, secure guy wires. Secure lower guy lines to base beam. Scope up mast. Secure upper guy lines and counter weight line. Set change house, fuel tank, compressor and air volume tank. Change oil in carrier motor and generator. Rig up communications tower and tie into office. Run and tie in circulating line to pump down tubing and take returns from 9-5/8" X 3-1/2" to choke manifold and gas buster. Install deadline block weight sensors. Install heater trunks to Dragon Fire Heater. Night Crew: Monitor equipment, install skirting around base of carrier and take on water to pits. 24 hour notice given to AOGCC for initial BOPE test on 2/20/2020. 02/17/2020 - Monday AK E-line arrive at KGF. PTW and Safety meeting. Mobe to location RU AK E-line. Build 2.5" x 30' glass nose bailer. Load bailer with crushed oyster shells. Shells keep getting clogged up upon entering the 2" port of bailer. 1 50 lb bag filled bailer. Stab on well. PT stack 250/3,500 psi. Well has been shut in for 24 hours. Open well and RIH. Tagged 4,042' uncorrected depth. Pick up and slack off to confirm tag. Dump oyster shells at 4,040'. POOH to surface. At surface string weight was 25 lbs heavier. Close swab valve. Bleed down and pop off. Remove bailer nose. Glass was confirmed broke. Bailer still full of oyster shells. 75% estimated to remain in Bailer. Call town to discuss. Decision made to rig down and let HAK 401 load well with oyster shells and displace to bottom. E-line rigged down and well turned over to 401 rig. Location secure. Transfer oyster shells and 3 50 lb sacks of bar rig crew. 24 hour notice given to AOGCC for initial BOPE test on 2/20/2020. Rig Start Date End Date 2/17/20 3/31/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KDU-02 50-133-20541-00 204-107 Rig up PJSM for well kill operations. Pump water down tubing with rig pump taking returns from 9-5/8" X 3-1/2" annulus and through choke manifold @ 2.2 bbl/min with 30 psi. Pumped 100 bbl without fluid returns. Shut in well. (Initial tubing and annulus pressure=200 psi, Final tubing pressure=Vacuum, Final annulus pressure = 230 psi.) Bleed annulus pressure down to 150 psi and monitor for 1 hour. After 1 hour annulus still at 150 psi and tubing on a vacuum. Resume pumping down tubing @ 1.5 bbl/min with 10-15 psi on tubing, annulus pressure dropping from 150 psi to 0 psi. 68 bbl pumped. Shut in and monitor well. Annulus 0 psi and tubing on a vacuum. Call town and discuss options. Decission made to rig up and dump oyster shells down tubing with water and displace to top of sand @ 4,042' WL measurements. Pin and hang rig floor landing. Rig up to dump oyster shells down tubing. Slowly dump oyster shells down tubing (tubing on a vacuum) while running a steady stream of water to prevent packing off in tree. Well packed off after 1-1/2 sacks of bar were added once oyster shells were down hole. Rig up to pump down pipe and pump 1/2 bbl of water before well pressured up to 1,550 psi. Shut down pumps and observed well pressure drop to 90 psi in 20 minutes. Run 50' cable snake down well without making contact with plug. Attempt to pressure up tubing then bleed off rapidly to back surge tubing multiple times to clear pipe with no luck. Discuss options with town and decision was made to call out WL and run bailer. Monitor well, blow down circulating and return lines, mount rig floor stairs, clear snow, fuel equipment and make ready for WL unit. Pollard Wireline on location. PJSM, Spot unit and rig up. M/U and RIH w/ 1-3/4" bailer with a chisel bottom. Tag plug @ 305'. Work bailer, POOH (bottom full of barite). Change out to a flapper bottom and RIH to 305'. Work bailer and POOH. (Retrieved 3 cups of barite) Change out bailer to 2-1/4" pump bailer and RIH. Work bailer and POOH. (Retrieved 2 cups of barite). Rerun 2-1/4" pump bailer. Work bailer and POOH. (Retrieved 3 cups of barite). Rerun 2-1/4" pump bailer. Work pump bailer @ 306' - Stuck. Work wireline (30 jar licks to 1900#) trying to free tool, unable to do so. Discuss options with wireline supervisor and decide to drop cut bar. Wait on cut bar from Pollard's shop to arrive. Pick up lubricator, Make up and drop cutter bar and cut wireline @ rope socket. Rig down Pollard Wireline. Secure and monitor well. Perform equipment checks, fuel equipment and clear snow. 02/20/2020 - Thursday Verify zero pressure on annulus. Continue snow removal from containments. Place anti-skid walkways around rig. Discussed plan forward with town. Decision made to nipple down tree and nipple up BOPE. Remove tree wing valves and assist production with removal of air control board for surface safety valve. Assist NOS wellhead tech with installation of BPV. Test Void/BPV 500 to 3,500 psi. Good test. Nipple down 5K production tree. Install blanking plug on top of BPV, Nipple up 13-5/8" 5M BOPE (11" 5M X 13-5/8" 5M DSA, Mud Cross, Double Gate and Annular), Reposition rig floor above annular. Connect Koomey lines and function test BOPE, HCR valve and choke. Night watch: Monitor rig equipment and well, set up light plants, hang tarps around cellar, install lights in cellar, make up 3-1/2" test joint, fuel rig equipment and housekeeping and maintenance as required. 02/19/2020 - Wednesday Connect Koomey lines and function test BOPE, HCR valve and choke. Decission made to rig up and dump oyster shells down tubing with water and displace to top of sand @ 4,042' WL measurements. Pin and hang rig floor landing. Rig up to dump oyster shells down tubing. Slowly dump oyster shells down tubing (tubing on a vacuum) while running a steady stream of water to prevent packing off in tree. Well packed Rig Start Date End Date 2/17/20 3/31/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KDU-02 50-133-20541-00 204-107 02/22/2020 - Saturday Verify zero pressure on annulus and tubing. R/U baiks and elevators. Break out TIW valve form landing joint. Rig up circulating line to annulus. Spot Pollard e-line unit. Assist rigging up Pollard to run punch holes in tubing above fish. RIH with e-line (tag top of fish @ 300' WLM). Correlate depth. Space out and fire gun. POOH w/ WL (gun did not fire). C/O tool, RIH and shoot 4 holes f/ 280'-279' WLM. Rig down Pollard e-line. R/U power tongs on rig floor, set and rig up lay down machine. Unseat hanger w/ 45K (string wt. 21K). Lay down landing joint and hanger. Break hanger off landing joint and load on NOS truck. Level rig while monitoring well. POOH f/ 2,085' to 1,830' laying down 8 joints (255') .5", 9.3# EUE Kill String Retrieve slick line bailer and drop cutter from jt # 9 and lay down same. Jt #10 (287'-319' out) full of oyster shells and barite. Pump 21 bbl water down back side to fill hole. (Hole taking ~2 bph) Repair shuttle chain on lay down machine. Continue to POOH f/ 1,766' laying down 3.5", 9.3# EUE Kill String. (saw some oyster shells in joints 12 & 13). Total of 66 joints pulled and layed down. Blow down and rig down circulating lines. Secure well. Night Watch: Monitor well , Fuel equipment, load 44 joints of kill string on trailer. Load 60 joints 3-1/2" 9.3# EU-Mod tubing on lay down machine pipe rack. 02/23/2020 - Sunday Verify zero psi on well and that hole was full. Start up carrier and service same. Serviced traveling equipment, pump out cellar box. Spot and rig up Pollard Slickline Unit. P/U 9.25" junk basket/drift. RIH with slickline, tag up at 4,011' KB (WLM). (Sat down at 1,938', picked up and passed through on second attempt) POOH and lay down tools. Junk basket full of oyster shells and barite. Rig down slickline. PJSM- P/U and RIH w/ 33 joints 3-1/2" 9.3# N-80 EU-Mod completion string to 1,041'. P/U X-Nipple (w/RHCM Installed) assembly- Galled threads in box on jt 33 and pin on bottom of X- Nipple assembly. Lay down jt 33 and replace with jt 131. Break out bottom pup on X-Nipple assembly and replace. Run jt # 34 and P/U 9-5/8" DLH packer assembly. Continue P/U and RIH w/ 3-1/2" 9.3# N-80 EU-Mod completion string total of 125 jts and 22 ' in on # 126 to 3,998' and tagged up. L/D jt 126, M/U hanger and land in well head. Packer @ 2,886'-2,894', X-Nipple @ 2,943' and EOT @ 3,992' Night Watch: Monitor well, Service and fuel equipment. R/D pipe lay down machine and HPU unit. Clear snow. 02/21/2020 - Friday R/U to test BOPE. Install TIW and Dart valve on 3-1/2" test joint. Connect remote BOP panel. Install rig floor stairs. Make up test joint to hanger. Grease Choke Manifold. Shell test BOPE (Annular, Dart Valve, #3 Kill and Choke #9 and 10.) 250/2,500 psi. Good Test While waiting on State witness to arrive: secured pit tarps, removed snow from around rig, c/o leaking needle valve, install heater trunk in Accumulator unit, prep and strap 3.5" EU-Mod tubing, completed containment in from of rig and secure BOP stack. Test BOPE as per Hilcorp and AOGCC standards. Test Annular 250 low / 2,500 high, Rams and Valves 250 low/ 3,000 high. Hold each test 5 min and chart same. Test PVT and gas alarm systems. (Good tests, no failures.) All tests witnessed by AOGCC rep. Adam Earl Blow down all BOPE and test equipment. Back out blanking sub and pull BPV. Remove ported sub from test joint and make up landing joint to hanger with TIW installed. Secure well for the night. Night Watch: Monitor well and equipment. Strap 3-1/2 EU-Mod tubing, fuel rig equipment, spot HPU and power tongs next to rig. Stage bales and elevators next to rig floor. Unseat hanger w/ 45K (string wt. 21K). Lay down landing joint and hanger. Break Continue to POOH f/ 1,766' laying down 3.5", 9.3# EUE Kill String P/U and RIH w/ 33 joints 3-1/2" 9.3# N-80 EU-Mod completion string to 1,041'. P/U X-Nipple (w/RHCM Installed) assembly-Galled threads in box on jt 33 and pin on bottom of X- Nipple a Test BOPE as per Hilcorp and AOGCC standards. Rig Start Date End Date 2/17/20 3/31/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KDU-02 50-133-20541-00 204-107 Verify zero pressure on well. Move heaters around due to loss of Dragon Heater. Warm and start up equipment, Thaw out circulating lines. Rig up to drop WTC 1-1/2" ball/bar. Line up to pump down tubing while bar dropping. Pressure tubing to 1,100 psi and hold, continue to pressure up to 2,000 psi and hold, continue pressure up to 3,500 psi and hold for 5 minutes to set packer as per manufature's repersentitive. Rig up and pressure test back side to 2000 psi. Hold for 30 minutes charted. Good Test. Install BPV as per NOS wellhead representative. Break bolts on 13-5/8" BOPE flanges. Blow down all BOPE and surface lines. Rig down choke and kill lines. Remove cellar tarps. Rig down floor (removed tools and rigged down power tongs)Remove rig floor stairs and fold up floor. Rig up lifting eyes on annular, pick up and lay down annular with rig blocks and hook and set on stump. Break off and remove double gate with blocks. Remove mud cross w/ valves and DSA. Nipple up 11" 5M X 3-1/8" 5M DSA with 3-1/8" 5M production tree to well head. Close master valve and make up 3-1/8" 5M wing valves and flow line. Secure well for the night. Night Watch: Cover tree and run heater trunk under cover. Fuel and service equipment. Load BOPE on trailer. Roll up and store Koomey hoses. 02/25/2020 - Tuesday Start up rig. Change out broken air fitting on air actuated safety valve on production flow line. Rig up air to same and remove cap to close valve for tree test. Begin pulling water out of pits for disposal. Assist NOS wellhead technician testing hanger void w/ 500 psi low for 5 minutes and 5,000 psi high for 15 minutes , GOOD TEST. Fluid pack and test tree w/ 5,000 psi , GOOD TEST Remove tree cap, assist NOS to pull blanking plug and BPV Assist Pollard slick line crew rigging up. Lower floor and hang sheave from blocks. Sim-Ops: Crew rig down total safety gas detection system, remote BOPE control panel and stage in accumulator unit. RIH w/ slick line and retrieve WCT packer setting ball/bar and RHCP from x-nipple. Sim-Ops: Blow down test pump manifold and freeze protect pump. Remove suction and discharge caps f/ mud pump and suck out residual water. Rig down Pollard slickline. Sim-Ops: Load Yellow Jacket equipment on trailer for return. Rig down NOV Rig Sense system (PVT, Hookload and Driller's Monitor). Rig down monkey board and unplug top section derrick lights. Remove upper guy wires. Scope down upper section and lay over mast. Secure cables and lines on carrier Remove carrier tarps. Raise carrier and mast jacks. Move carrier off well and park on south side of location. Night Watch: Fuel and monitor equipment. Stage equipment on south side of location. Pull liner material and felt that was under pumps, pits and carrier. 02/26/2020 - Wednesday Stage remaining equipment on south side edge of location. Pull up remaining liner and felt material and fold up for disposal. Clear snow and ice from where rig was setting and around well head. 02/24/2020 - Monday run tubing and set packer. Rig up to drop WTC 1-1/2" ball/bar. Line up to pump down tubing while bar dropping. Nipple up 11" 5M X 3-1/8"5M DSA with 3-1/8" 5M production tree to well head. . Rig up and pressure test back side to 2000 psi. Rig Start Date End Date 2/17/20 3/31/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KDU-02 50-133-20541-00 204-107 03/03/2020 - Tuesday PTW, JSA with SLB CT crew, Cruz crane operator and Hilcorp. WHP 0 psi, IA 0 psi. Fire equipment. Transfer liquid N2 from transport to N2 pump. Pick injector head. Make up reverse FCO BHA. 1.75" OD coil connector, 1.75" OD x 3.83' MBT, 1.75" OD x 3.83' MBT, o over 1.85" OD x .33', x over 1.9" OD x .33', big hole reverse nozzle 2.2" OD x .580'. Stab on well. Open well RIH 20' Close pipe rams and slips. PT lubricator to 250/3,500 psi. Good test. N2 cooled down. Load 2x 50 bbl tanks of batch mixer wtih 3% KCL. Mix in gel. Prep for mixing foamer. RIH , pipe displacement building WHP indicating fluid is at surface. 3,000' perform weight check. Online down 3.5" production tubing with N2 only at 600 scf/min. Park coil at 3,200' wait for returns. DIrty returns to surface. Unload 80 bbls of water from tubing. N2/fluid returns to surface. Online with foam down CT at .7 bbls/min and N2 750 scf/min. RIH and tagged fill at 3,361'. Pick up and start reversing out from 3,361' stacking 1,000-1,500 lbs and letting weight come back. Take 10' bites and pick up 25' Continue cleaning out until hard tag at 4011'. Attempt to stack 20K down. No weight breaking. 7 attempts made to break through at 4,011'. RIH at 100 ft/min stacking 18k. Possibly tagging top of BAR that was dumped ontop of oyster shells to create a barrier to isolate formation from fluid loss. Decision made to POOH to surface. Foam quality is great. Not able to see solids in foam. Tagged up at surface. Close master valve. Blow Coil reel dry with N2 for freeze protect. Blow back and freeze protect lines. Haul away 4 vac truck loads of returns. Sent 240 bbls to G&I facility. Add 3% KCL to supply tank. 125 bbls pumped 3 % KCL. 154,000 scf. PTW, JSA with SLB CT crew, Cruz crane and vac truck operators, Hilcorp well site representative. Lay pit liner for equipment. Spot in Coil unit, fluid pump, N2 pump. Spot rain for rent supply and return tanks. Unload Weaver float with auxiliary coil equipment, lubricator box, pump iron rack, return iron rack, BOPE stand, and choke skid. Unload 6 pallets of KCL with 56 sacks of 50 lb bags per pallet at G&I facility. Mix 55 sack per 60 bbl vac truck load into 400 bbl supply tank. Install BOPE, run iron. BOPE test witness notification sent via AOGCC web based notification on 2/28/20 @ 1332 hrs. BOPE test witness waived by Jim Regg via email reply on 2/28/20 at 1501 hrs. Start test. Test all rams and valves 250/3,500 psi. Perform accumulator draw down test. BOPE test completed. Install ground thaw glycol heater hoses into 400 bbl supply tank loaded with 240 bbls of 3% KCL. Install 30'x40' tarp over open top tank and secure with sache cord. Inventory gel, and foam surfactant. Discuss mix/dilution ratios with crew. Review proper mixing procedures. 03/01/2020 - Sunday PTW, JSA with SLB, Cruz construction and Hilcorp. Fire equipment. Pick injector head. Stab on well. Prep for loading fluid and foamer to coil pump displacement tanks. Function test boat motors (mixing paddles.) One mixing motor not functioning and the other barley turning. Discuss options. Pop off well. Rig back injector head and install night cap. SLB coil crews headed back to shop to dig out batch mixer to inspect. Head to Swanson River. Mobilize hot oil truck to Beaver Creek for following job tomorrow. 02/29/2020 - Saturday CTU FCO RIH and tagged fill at 3,361'. Pick up and start reversing out from 3,361' stacking 1,000-1,500 lbs and letting weight come back. T Rig Start Date End Date 2/17/20 3/31/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KDU-02 50-133-20541-00 204-107 03/31/2020 - Tuesday Met With Reservoir Engineer about adding more perforations. Decision was made to close out well. PTW, JSA with SLB coil, Cruz crane and vac truck operators, Hilcorp wellsite supervisor. Fire equipment. Pick injector head. MIRU SLB pump truck. Function test pump. Make up Yellow Jacket BHA. 2.13" OD external slip coil connector, 2.13" OD DFCV, 2.125" OD BiDi jars, 2.125" TJ Hydraulic disconnect 5/8" ball, 2.125" OD dual circ sub 1/2" ball, 2.125" motor, 2.75" 3 blade junk mill. Fluid pack 1.75" coil with 33.7 bbls of 3 % KCL. PT 250/3,500 psi. Good pt on MHA. Stab on well. PT stack 250/3,500 psi. Transfer N2 from Air liquid transport to SLB N2 pump. Fill 2 x 50 bbl batch mixer tanks with 3 % KCL. Mix in Flo-VisL gel. Open well. 1,450 psi WHP (N2 pressure from previous FCO). RIH and bleed down WHP. Tag 4,011' -5k down. Pick up clean 4,500 lbs. Online down CT with 3% KCL. 1.2 bbls/min 3061 psi free spin. stack 1,000 lbs at 4,011'. 250 psi motor work. ROP increase and motor work dropped off at 4,015'. N2 cooling down. PT N2 lines to 250/3,500 psi. 4,096' Hard stall. PU clean. RIH and passed 4,069'. Wash/mill to 4,140' (top of upper per) Stall motor. PU Lost returns. Online down CT with 750 scf/min and .7 bbls/min of foam. Contiue POOH. N2/foam returns to surface while POOH with coil at 2,290'. RIH. Pinch in choke holding 350 psi WHP. CT at 4,197' 3,750 psi circ 350 psi WHP. 950 scf/min .67 bbls/min foam. Clean out to 4,351'. make 4 wiper trips from 3,950' to 4,351'. Good oyster shell and sand returns to surface. Drop 1/2" ball to open circ sub. Circ sub sheared at 3,800 psi coil pressure with N2. Fluid/foam pump shut down. Pumping N2 only to lift remaining well bore fluids. CT parked at 4,351'. N2 lift well. Fluid returns stopped. N2 at surface. POOH from 4,351' POOH with CT. N2 offline. Pinch in choke to hold back pressure WHP 450 psi. Tagged up at surface. Shut in well. 280 psi SITP. Pop off well to break down Motor and mill assembly. Install night cap on BOPE. Open well to bleed down N2 while breaking down BHA. Rig back CTU injector head. 324 psi 95% LEL. Shut in well. 3,754 gallons of N2 pumped. 185 bbls of fluid/foam pumped for job. Returned 213 bbls total for job. Wellbore gave up 28 bbls. Return tank and supply tank empty. Remaining surface fluids sent to G&I. Remove heater hose/ground thaw unit from supply tank. Rig down N2 lines and batch mixer. Well site secure. Turn well over to production to flow. SDFN. 03/04/2020 - Wednesday PTW, JSA with SLB crew, Ctruz, yellow jacket and Hilcorp. Pick injector head. Stab 2 x 10' lubricators. Make up external slip coil connector on 1.75" CT. Pull test 25k. SLB pump not going into gear. Call out mechanic. SLB still not able to figure out problem. Rack back injector head. Install night cap on BOPE stack. Rig down SLB pump truck and send back to shop. Top off ground thaw unit heater. Supply tank refilled with 350 bbls of 3% KCL. Park triplex in auto shop for night. 03/05/2020 - Thursday 2.75" 3 blade junk mill. stack 1,000 lbs at 4,011'. 250 psi motor work. ROP increase and motor work dropped off at 4,015'.N2 cooling down. PT N2 FCO oyster shells and barite. _____________________________________________________________________________________ Updated by DMA 04-09-20 SCHEMATIC Kenai Gas Field Well: KDU 02 Last Completed: 8/21/1968 PTD: 168-049 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor N/A Surf 58' 13-3/8' Surface 54.5 / J-55 / STC 12.615 Surf 1,317' 9-5/8" Intermediate 40 / N-80 / Seal Lock 8.835 Surf 6,027' 7" Liner 29 / N-80 / BTC 6.184 5,821’ 10,522' TUBING DETAIL 3-1/2" Tubing 9.2 / N-80 / Butt Mod 2.992 Surf 3,992’ JEWELRY DETAIL No Depth Item 1 2,886’ Packer 2/23/20 1A 4,370’ Posiset Plug 2 5,007’ Cement Retainer 3 5,385’ Cement Retainer 4 5,921’ Cement Retainer 5 7,861’ Cement Retainer 6 9,325’ Cement Retainer 7 9,500’ Baker Packer 8 9,744’ Junk Retainer 9 9,750’ Cement Retainer 10 9,950’ Cement Retainer 11 10,436’ Junk Retainer 12 10,477’ Cement Retainer OPEN HOLE / CEMENT DETAIL 13-3/8" Cmt w/ 650 sks of class "G" 9-5/8" Cmt w/ 700 sks of class "G" through shoe& w/ 300 sks thru DV tool @1918' 7” Cmt w/ 1000 sks of class "G" ACTIVE PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Sterling A8 4,140’ 4,150’ 3,659’ 3,668’ 10 1/28/2020 Open Sterling A11 4,310' 4,350' 3,804' 3,839' 40 4/28/2016 Open Sterling B1 4,380' 4,420' 3,865' 3,900' 40 3/30/2016 Isolated ISOLATED PERFORATION DETAIL Sterling Pool 6 5,119' 5,120' 4,538' 4,539' 1' 5/17/2013 Squeezed 5,128' 5,138' 4,546' 4,556' 10' 5/17/2013 Squeezed 5,170' 5,190' 4,586' 4,605' 20' 5/17/2013 Squeezed 5,235' 5,265' 4,648' 4,676' 30' 5/17/2013 Squeezed UT / 72-8 7,911' 7,951' 7,276' 7,280' 40 3/18/1996 Squeezed UT / 73-1 7,973' 7,992' 7,338' 7,357' 19 3/18/1996 Squeezed UT / 75-8 8,220' 8,262' 7,584' 7,626' 42 11/29/1995 Squeezed Upper Ty/Bel 8,245' 8,255' 7,609' 7,618' 10' Nov-95 Squeezed Tyonek 9,510' 9,522' 8,874' 8,886' 12' 8/13/1968 Isolated 9,558' 9,588' 8,922' 8,952' 30' 9,854' 9,874' 9,218' 9,238' 20' 8/4/1974 Squeezed / Isolated (8/8/1974) 9,884' 9,910' 9,248' 9,274' 26' 9,919' 9,920' 9,283' 9,284' 1' 10,006' 10,007' 9,370' 9,371' 1' 7/27/1974 10,028' 10,036' 9,392' 9,400' 8' 8/13/1968 10,080' 10,092' 9,443' 9,455' 12' 8/13/1968 THE STATE ALASKA GOVERNOR MIKE DUNLEAVY Taylor Wellman Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Kenai Gas Field, Sterling 3 Gas, KDU 2(21-8) Permit to Drill Number: 168-049 Sundry Number: 320-070 Dear Mr. Wellman: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Ww .aogcc.alaska.gov Enclosed is the approved application for the 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, VChair rice DATED this\5day of February, 2020. RBDMS� 54 FLb 14 2020 RECEIVED STATE OF ALASKA FEB 0 7 2020 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS A®GCC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Rw Operations shutdown ❑ Suspend ❑ Perforate C1 MAI Other Stimulate ❑ Pull Tubing Q 2 Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: N2 ❑Q 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q. Stratigraphic ❑ Service ❑ 168-049 s 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-133-20121-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 510A ' Will planned perforations require a spacing exception? Yes ❑ No Q Kenai Deep Unit (KDU) 2(21-8) 9. Property Designation (Lease Number): 10. Field/Pool(s): J FEDA028142 - Kenai Gas Field / Sterling 3 Gas it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10,522' . 9,885' 4,355' 3,843'–146psi 4,366' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 58' 20" 58' 58' Surface 1,317' 13-3/8" 1,317' 1,295' 2,730psi 1,130psi Intermediate 6,027' 9-5/8" 6,027' 5,412' 5,750psi 3,090psi Production Liner 4,701' 7" 1 10,522' 9,885' 8,160psi 7,020psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 3-1/2" 9.2# / N-80 2,085' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A; N/A N/A; N/A 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑Q Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: February 20, 2020 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑Q WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Taylor Wellman 777-8449 Contact Name: Ted Kramer Authorized Title: Operations ger Contact Email: tkmmerrrahilcere.cem Contact Phone: 777-8420 Authorized Signature: Dale: -1-1--1121 w COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: fz, 40\ Plug Integrity F1�OP Test u Mechanical Integrity Test ❑ Location Clearance ❑ Other: x 3 I<- aS-6c,r"s- r.^ a RBDMS±� FEB 14 2020 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No L`r r–,� Subsequent Form Required: U •— cl Q / V, APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: /y1� 3 Forrpgp-a" oa Revis o17 V a'��• 70 Approved application is n I ^ I A /�"" li tbC1f r6atisL1� ate of approval. ' ` 1 VVV !!!"'111 •7��"O �bmit roan mw gnachments in Duplicate ` 16/ko CC" U flile rp Alaska, LU Well Prognosis Well: KDU 02 Date: 2/05/2020 Well Name: KDU 02 API Number: 50-133-20121-00-00 Current Status: Shut -In Gas Producer Leg: N/A Estimated Start Date: February 20, 2020 Rig: E -Line/ 401 /Coil Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 168-049 First Call Engineer: Ted Kramer (907) 777-8420 (985) 867-0665 (C) Second Call Engineer: Christina Twogood (907) 777-8443 (907) 378-7323 (C) AFE Number: Current BHP: Max. Expected BHP: Max. Potential Surface Pressure: Brief Well Summary - 250 psi @ 3,804' TVD - 530 psi @ 3,839' TVD - 146 psi (Calculated from offset well KU 11-08 Static BHP Survey on 3/7/2013) (Based on offset well RFT data from 04/04/2017) (Based on expected BHP and gas gradient to surface (0.10psi/ft)) In 1968, KDU 02 was drilled and completed in the Tyonek D. It was perforated in the D4D and D413 as well as the D3C (strong water drive sand). It was ± + ^cele-io Y Upper Tyonek in 1995; eventually being recompleted to the Beluga and Sterling. The well was shut-in in 2013. S*c—el_ — miler t5 Pte: �— �"ep- e-ma� 1 7�or Notes Regarding Wellbore Condition l—re Vis 6 Ove • The well is currently shut-in. 1 P�,A/� L 31l _ S 7 / n • Minimum ID is 2.992". • Last tag @ 4,817' KB w/ 2.5" Centralizer and 1.75" Sample Bailer on 4/16/2016. Safety Concerns • Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. • Considertank placement based on wind direction and current weather forecast (venting nitrogen during this job). • Ensure all crews are aware of stop job authority. E -Line Procedure 1. MIRU E -Line and pressure control equipment. PT lubricator to 250 psi Low/ 2,000 psi High. 2. PU RIH W/ inflatable packer to 4,130' (+/-). Set same. POOH W/ E -line. 3. PU Dump Bailer, RIH and Dump Bail 20' of Sand. TO sand @ 4,110 (+/-). POOH W/ E -line. Well Prognosis Well: KDU 02 Hilmrp Aleska, LU Q Date: 2/05/2020 Rig 401 Procedure F ' P -0 r 4. Circ. Fluid to fluid pack well above packer. (Note: Fluid needs to be weighted properly and pumped properly to not fail inflatable packer with Hydrostatic pressure.) 5. MIRU Rig 401. ND Well head, NU BOP and test bop 250psi low / 3,000 psi high, annular to1586` psi. (hold each valve and test for 5 -min). Record accumulator pre -charge pressures. • Notify AOGCC 24hrs in advance to witness test. • Crew will be working 12hr shifts and well will be secured nightly with TIW valves and BOPE. • Test VBR rams on 3-1/2" test joint. • Email completed 10-424 form to all AOGCC addresses listed on the form within 5 days of BOPS test. 6. Insure no pressure on tubing or back side. Re-cCirculate well if necessary. 7. POOH W/ Kill s� racking back tubing. K+t 8. PU WEG, Tubing, and packer. RIH and space out packer at 2,900', EOT at 4,100' (+/-). 9. Hang off tubing, ND BOP, NU wellhead and test. 10. RU E -line. PT lubricator to 250 psi Low / 3,000 psi High. / 11. PU RIH with RBP to 3,000' and set. 12. Pressure up on tubing according to manufacturer's setting procedure to set packer. 13. Pressure test back side to 2,000 psi on chart for 30 min., (� " 14. Unset RBP, POOH. 15. RDMO Rig 401. r/ Coil Tubing Procedure c ` 16. MIRU CTU. Pressure test BOP to 250 psi Low / 3,000 psi High. RU Nitrogen. l✓�v 17. RIH W/ Coil lifting out fluid with nitrogen as go. Remove as much water as possible from well. �r 1 Note: Pressure differential across the inflatable packer need to be kept within tolerance or the hydrostatic could fail the inflatable packer. y 18. Circulate Sand off the top of the inflatable packer. 19. Latch inflatable packer and pull out of well. 20. RDMO Coil 21. Turn well over to production. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. BOP Schematic (Rig 401) 4. BOP Schematic — Coil 5. Current Wellhead Schematic 6. Standard Well Procedure—N2 Operations 7. Blank RWO Change Form Kenai Gas Field SCHEMATIC Well: KDU02 Last Completed: 8/21/1968 caro Alaska. LLC PTD: 168-049 RKB: MSL=107' 29 U IBP a AB TOC @4,355' All _ Bl 1 -- 2 y 3 TOC@ 5,750' s5/s' I f Ba w a, 7,9 TOF Ta 8,432' TD =10,522' MD/ 9,885' TVD PBTD= 4,355MD/ 3,843' TVD CASING DETAIL Size Type Wt/Grade/Conn ID Topd37 Posiset Plug 20" Conductor N/A 3 Surf Cement Retainer 13-3/8' Surface 54.5/1-55/STC 12.615 Surf 9-5/8" Intermediate 40/N-80/Seal Lock 8.835 Surf Baker Packer 7" Liner 29 / N-80 / BTC 6.184 5,821' TUBING DETAIL 3-1/2" Tubing 9.2 / N-80 / ButtMod 1 2.992 1 Surf 2,085' JEWELRY DETAIL No Depth Item 1 4,374 Posiset Plug 2 5,007' Cement Retainer 3 5,385' Cement Retainer 4 5,921' Cement Retainer 5 7,861' Cement Retainer 6 9,325' Cement Retainer 7 9,500' Baker Packer 8 9,744' Junk Retainer 9 9,750' Cement Retainer 10 9,950' Cement Retainer 11 10,436' Junk Retainer 12 10,477' Cement Retainer ACTIVE PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) (TVD) FT Date Status Sterling AB 4,140' 4,150' 3,659' 3,668' 10 1/28/2020 Open Sterling All 4,310' 4,350' 3,804' 3,839' 40 4/28/2016 Open Sterling 81 4,380' 4,420' 3,865' 3,900' 40 3/30/2016 Isolated ISOLATED PERFORATION DETAIL OPEN HOLE / CEMENT DETAIL 13-3/8" 1 Cmt w/ 650 sks of class "G" 9-5/8" 1 Cmt w/ 700 sks of class "G" through shoe& w/ 300 sks thru DV tool @1918' 7" 1 Cmt w/ 1000 sks of class "G" Updated by DMA 02-03-20 5,119' 5,120' 4,538' 4,539' 1' 5/17/2013 Squeezed Sterling Pool 5,128' 5,138' 4,546' 4,556' 30' 5/17/2013 Squeezed 5,170' 5,190' 4,586' 4,605' 20' 5/17/2013 Squeezed 5,235' 5,265' 4,648' 4,676' 30' 5/17/2013 Squeezed UT/72-8 7,911' 7,951' 7,276' 7,280' 40 - 3/18/1996 Squeezed UT/73-1 7,973' 7,992' 7,338' 7,357' 19 3/18/1996 Squeezed UT/75-8 8,220' 8,262' 7,584' 7,626' 42 11/29/1995 Squeezed Upper Ty/Bel 8,245' 8,255' 7,609' 7,618' 10' Now95 Squeezed 9,510' 9,522' 8,874' 8,886' 12' Isolated 8/13/1968 9,588' 8,922' 8,952' 30' 9,854' 9,874' 9,218' 9,238' 20' Squeezed/ 9.884' 9,910' 9,248' 9,274' 26' 8/4/1974 Tyonek 9,919' 9,920' 9,283' 9,284' 1' 10,006' 10,007' 9,370' 9,371' 1' 7/27/1974 Isolated 10,028' 10,036' 9,392' 9,400' 8' 8/13/1968 (8/8/1974) 10,080' 10,092' 9,443' 9,455' 12' 8/13/1968 OPEN HOLE / CEMENT DETAIL 13-3/8" 1 Cmt w/ 650 sks of class "G" 9-5/8" 1 Cmt w/ 700 sks of class "G" through shoe& w/ 300 sks thru DV tool @1918' 7" 1 Cmt w/ 1000 sks of class "G" Updated by DMA 02-03-20 ff Nd."r,dla-ka. Lu: RKB: MA =107' 20' I PROPOSED SCHEMATIC AA L<- 1, A Z10�r5: TOC P4.355' Al 4 In to K -s 2 • 3 TOC@ 5,750' -- 9-5/8• 1 Mai Colla Casco 7,931 TOF Tag 8,432' - TD =10,522'MD / 9,885' TVD PBTD = 4,355' MD / 3,843' TVD CASING DETAIL Kenai Gas Field Well: KDU 02 Last Completed: 8/21/1968 PTD: 168-049 Size Type Wt/Grade/Conn ID Top Btm 20" Conductor N/A 2 Surf 58' 13-3/8' Surface 54.5/1-55/STC 12.615 Surf 1,317' 9-5/8" Intermediate 40/N-80/Seal Lock 8.835 Surf 1 6,027' 7" Liner 29/N-80/BTC 6.184 5,821' 1 10,522' TUBING DETAIL 3-1/2" Tubing 9.2/N-80/Butt Mod 1 2.992 1 Surf 4,100' JEWELRY DETAIL No Depth Item 1 2,900' Packer lA 4,370' Posiset Plug 2 5,007' Cement Retainer 3 5,385' Cement Retainer 4 5,921' Cement Retainer 5 7,861' Cement Retainer 6 9,325' Cement Retainer 7 9,500' Baker Packer 8 9,744' Junk Retainer 9 9,750' Cement Retainer 10 9,950' Cement Retainer 11 10,436' Junk Retainer 12 10,477' Cement Retainer ACTIVE PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (ND) (TVD) FT Date Status Sterling A8 4,140' 4,150' 3,659' 3,668' 10 1/28/2020 Open Sterling All 4,310' 4,350' 3,804' 3,839' 40 4/28/2016 Open Sterling B1 4,380' 4,420' 3,865' 3,900' 40 3/30/2016 Isolated ISOLATED PERFORATION DETAIL OPEN HOLE/ CEMENT DETAIL 13-3/8" Cmt w/ 650 sks of class "G" 9-5/8" Cmt w/ 700 sks of class "G" through shoe& w/ 300 sks thru DV tool @1918' 7" Cmt w/ 1000 sks of class "G" Updated by DMA 02-05-20 5,119' 5,120' 4,538' 4,539' 1' 5/17/2013 5,128' 5,138' 4,546' 4,556' 10' 5/17/2013 Sterling Pool 5,170' 5,190' 4,586' 4,605' 20' 5/17/2013 5,235' 5,265' 4,648' 4,676' 30' 5/17/2013 UT/72-8 7,911' 7,951' 7,276' 7,280' 40 3/18/1996 d qSqueezed UT/73-1 7,973' 7,992' 7,338' 7,357' 19 3/18/1996 UT/75-8 8,220' 8,262' 7,584' 7,626' 42 11/29/1995UpperTy/Bel 8,245' 8,255' 7,609'7,618' 10' Nov -95 9,510' 9,558' 9,522' 9,588' 8,874' 8,922' 8,886' 8,952' 12' 30' 8/13/1968 Isolated Tyonek 9,854' 9,884' 9919' 9,874' 9,910' 9,920' 9,218' 9,248' 9,283' 9,238' 9,274' 9,284' 20' 26' 1' 8/4/1974 Squeezed/ 10,006' 10,007' 9,370' 9,371' 1' 1/27/1974 Isolated 10,028' 10,036' 9,392' 9,400' 8' 8/13/1968 (8/8/1974) 10,080' 10,092' 9,443' 9,455' 12' 8/13/1968 OPEN HOLE/ CEMENT DETAIL 13-3/8" Cmt w/ 650 sks of class "G" 9-5/8" Cmt w/ 700 sks of class "G" through shoe& w/ 300 sks thru DV tool @1918' 7" Cmt w/ 1000 sks of class "G" Updated by DMA 02-05-20 o� YELLOWACKE OILFIELD SERVICES I` 13-518" 5M DOUBLE BOP STACK A FORGED ANNULAR 35/8" 5M IWS DOUBLE RAM BOP 7/8" TO 5" VBR RAMS IN TOP BORE LIND RAMS IN BOTTOM BORE 4-1-16" 5M GATE VALVES 4-1116" X 2-1/16" DSA ON ENDS TO CO -FLEX 11" 5M DSA TOTAL STACK HEIGHT 106.3 INCLUDING BOTTOM DSA OPEN AND CLOSE DATA OPEN CLOSE 13-5/8" 5M ANNULAR 17.41 23.58 135/8" 5M RAMS PER CAVITY 4.7 5.34 4-1116" 5M HCR 0.61 0.52 2' 1502 x 2-11 Ranged W (Mansel 2-1/16 1OK 10K Flange (Manu Coil Tubing BOP Coiled Tubing HR580 Injector Head & Gooseneck Weight = 12,850 lbs 4-1116" 1OK Conventional Stripper SK 0062 Lubricator SK 0062 x 4-1/16" 1OK Flange 4-1116" 10K Combi BOP Tap Set avd/Shear SecmdselF elsllp 4-1/16" 10K Flow Cross Manuel 2x2 Valve 1. 2" 1502 x 2.1/16" 1OK Flange Man a 2x2 Valve 2: 2-1/16" 1OK x2-1/16' 1OK Flange Manual 2x2 Valva 3: 2-1116" IOK x 2-1/16" 1OK Flange Manuel 2x2 Valve 4: 2" 1502 x 2.1/16' 1OK Flange 4-1/16" 1OK x Wellhead Adapter Flange Wellhead H HA.T AIn.L.. LIA: Kenai Gas Feld KDU #2 133/8 X 95/8 X 31/2 Valve, swab,WKM-N 3 1/8 SM FE, H WO, T - Tee, stdd, 3 1/8 51v 3 1/8 SM Valve, upper master, WKM-M, 31/85M FE, HWC T-24 Valve, lower master, WKM-M, 31/85M FE, HWC T-24 Tubing head, CIW-DCB, 13 5/8 3M X 11 5M, w/ 2- 2 1/16 5M SSO, X -bottom prep, I% VR profile Casing head, Shaffer KD, 13 5/8 3M X 13 3/8 SOW, w/ 2- 2" LPO, Kenai Gas Field KDU #2 02/06/2020 Tree cap Otis, 3 1/8 5M FE X 6 % Otis Quick Union Tubing hanger, CIW-DCB- FBB, 11 X 3 % EUE 8rd lift and 3 % EUE susp, w/ 3" type H BPV profile, 6 1/4" EN, %" non continuous control line re, Wing, 1/8 5M FE, w/ A oper, DD trim W-FBB, 11 SM FE X prepped for 6 X" eck, 1/2npt control ine port ve, CIW-FC, 2 1/16 SM FE, HWO, AA 2"LP CIW ball valve 11 STANDARD WELL PROCEDURE I bleorp Alaska, LIT NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre -job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4 -gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL vl Page 1 of 1 s 0 Mi 0 i a V O a a C N 0 L RX O rL 4 IxO 2 0) JZU a) L o v m .O co U L _ U C N E E E rn 0.9 U C cpE — o 3 a TE v` a) c N � c� >a o � n= 0.a m 0 c ` N o � N c o m m L C U M N L Uw 0 > a C' as o c 0. m 3 cU e7 U c0 c O m E d U m a a> c L N 3 U T N c, N O O � a(D n > Cc o C Y cc O o 3 N 0 0 Co 0 T a o U EO c0 a¢ 0 CL n w as 0 E4 11 Y m D LL a1 � c6 V � C cc U m Uc C9oN O 0 Q as a-- > a°mw = a c Q NN Y m an< m 2 d c 0 a C. - M Cl �z y �> Z a. d rn c ns t U 3 d U O a Y O d R a d TT N 0 CL n w as 0 E4 11 Y m D LL Boyer, David L (CED) From: Christina Twogood - (C) <ctwogood@hilcorp.com> Sent: Monday, February 10, 2020 3:18 PM To: Boyer, David L (CED) Cc: Ted Kramer; Donna Ambruz Subject: RE: [EXTERNAL] KDU 2(23-8) - (PTD 168-049; Sundry 320-070) - Question Attachments: KDU-02 AOGCC 10-403 Approved 12-23-19.pdf; KDU-02 AOGCC 10-403 Submitted 02-07-20.pdf Hi Dave, That is correct, no new perforations will be added to KDU 2 (21-8) in any zone at this time. I believe the sundry most recently submitted does not have the perforate box checked, however there may have been some confusion based on the oversight with the statement discussed in previous email. I have attached the previous KDU-2 (21-8) Approved Sundry 319-578 for perforations and the current KDU-2 (21-8) sundry (submitted 2-7-2020) to install the upper completion w/ packer. Hopefully this clears things up however feel free to reach out if I can provide any further clarification. Respectfully, Christina Twogood Operations Engineer Kenai Asset Team, Hilcorp Alaska 3800 Centerpoint Dr., Anchorage, AK 99503 (w) 907-777-8443 (c) 907-378-7323 From: Boyer, David L (CED) [mailto:david.boyer2@alaska.gov] Sent: Monday, February 10, 2020 2:39 PM To: Christina Twogood - (C) <ctwogood@hilcorp.com> Subject: RE: [EXTERNAL] KDU 2(23-8) - (PTD 168-049; Sundry 320-070) - Question Hi Christina, I am handling this sundry in Steve's absence with no previous involvement. lust for clarification since the box for perforate was checked on the cover page under Type of Request: No new perforations will be added to KDU 2(21-8) in any zone at this time. Please confirm and I will make the corrections throughout both copies of the 10-403. Thank you, Dave Boyer AOGCC From: Christina Twogood - (C) <ctwogood@hilcorp.com> Sent: Monday, February 10, 2020 11:02 AM To: Davies, Stephen F (CED) <steve.davies@alaska.gov> Cc: Boyer, David L (CED) <david.boyer2Palaska.gov>; Ted Kramer <tkramer@hilcorp.com>; Donna Ambruz <dam bruz@hilcorp.com> Subject: RE: [EXTERNAL] KDU 2(23-8) - (PTD 168-049; Sundry 320-070) - Question Steve, Apologies for the oversight on this statement. The sundry application should read as follows: "The purpose of this work/sundry is to remove the kill string and install an upper completion w/ packer." Please let me or Ted know if you have any further questions regarding this work. Kind Regards, Christina Twogood Operations Engineer Kenai Asset Team, Hilcorp Alaska 3800 Centerpoint Dr., Anchorage, AK 99503 (w) 907-777-8443 (c) 907-378-7323 From: Davies, Stephen F (CED) [mailto:steve.davies@alaska.gov] Sent: Friday, February 7, 2020 4:54 PM To: Christina Twogood - (C) <ctwogood@hilcorp.com> Cc: Boyer, David L (CED) <david.boyer2@alaska.gov> Subject: [EXTERNAL] KDU 2(23-8) - (PTD 168-049; Sundry 320-070) - Question Christina, The Brief Well Summary of Hilcorp's Sundry Application states the purpose of the sundry is to add perforations in the Sterling A8 and A-10 sands. But I don't see any proposed perforation depths listed in the Rig procedures or on the Proposed Schematic drawing. Or have I missed something? I will be out of the office next week, so please reply to David Boyer with a cc to me. Thank you, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or steve.daviesCaalaska.gov. Boyer, David L (CED) From: Christina Twogood - (C) <ctwogood@hilcorp.com> Sent: Monday, February 10, 2020 11:02 AM To: Davies, Stephen F (CED) Cc: Boyer, David L (CED); Ted Kramer; Donna Ambruz Subject: RE: [EXTERNAL] KDU 2(23-8) - (PTD 168-049; Sundry 320-070) - Question Steve, VX,4 Apologies for the oversight on this statement. p� r The sundry application should read as follows: "The purpose of this work/sundry is to remove the kill string and install an upper completion w/ packer." Please let me or Ted know if you have any further questions regarding this work. Kind Regards, Christina Twogood Operations Engineer Kenai Asset Team, Hilcorp Alaska 3800 Centerpoint Dr., Anchorage, AK 99503 (w)907-777-8443 (c) 907-378-7323 From: Davies, Stephen F (CED) [mailto:steve.davies@alaska.gov] Sent: Friday, February 7, 2020 4:54 PM To: Christina Twogood - (C) <ctwogood@hilcorp.com> Cc: Boyer, David L (CED) <david.boyer2@alaska.gov> Subject: [EXTERNAL] KDU 2(23-8) - (PTD 168-049; Sundry 320-070) - Question Christina, The Brief Well Summary of Hilcorp's Sundry Application states the purpose of the sundry is to add perforations in the Sterling A8 and A-10 sands. But I don't see any proposed perforation depths listed in the Rig procedures or on the Proposed Schematic drawing. Or have I missed something? I will be out of the office next week, so please reply to David Boyer with a cc to me. Thank you, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or steve.daviesPalaska.zov. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED FEB 0 7 2020 1. Operations Abandon Lj Plug Perforations Ll Fracture Stimulate Lj Pull Tubing LA'moi _r�s_Fiutdown Li Performed: Suspend ❑ Perforate ❑� Other Stimulate ❑ Aller Casing ❑ C ange pprove Program ❑ Plug for Redrill ❑ erforale New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: N2 + Flow Test ❑✓ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development ❑✓ Stratigraphic❑ Exploratory ❑ Servioe ❑ 168-049 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-133-20121-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028142 Kenai Deep Unit 2 (21-8) 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kenai Field / Beluga -Upper Tyonek & Sterling 6 Gas 11. Present Well Condition Summary: Total Depth measured 10,522 feet Plugs measured 4,355 feet true vertical 9,885 feet Junk measured N/A feet Effective Depth measured 4,355 feet Packer measured 9,500 feet true vertical 3,843 feet true vertical 8,864' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 58' 20" 58' 58' Surface 1,317' 13-3/8" 1,317' 1,295' 2,730psi 1,130psi Intermediate 6,027' 9-5/8" 6,027' 5,412' 5,750psi 3,090psi Production Liner 4,701' 7" 10,522' 9,885' 8,160psi 7,020psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.2# / N-80 2,085' 1,955' Packers and SSSV (type, measured and true vertical depth) N/A N/A N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13, Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 4203 280 188 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations ED Exploratory❑ Development0 Service ❑ Stratigraphic ❑ 16. Well Status after work: Oil Gas WDSPLLJ Copies of Logs and Surveys Run ❑ 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: 319-578 Authorized Name: Taylor Wellman 777-8449 Contact Name: Ted Kramer Authorized Title: O s Man r ContactEmail: lkramer(dhilcom.com Authorized Signature: Date: Z Z, 11[ Contact Phone: 777-8420 Form 10-404 Revised 4*6pMS-140,. FEB 10 2020 "10-A O Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date KDU-02 E -Line 50-133-20541-00 1 204-107 1/28/20 1/28/20 Daily Operations: 01/28/2020 -Tuesday Sign in. Mobe to location. PTW and JSA. Spot equipment and rig up lubricator. PT to 250 psi low and 2,000 psi high. TP - 269 psi. RIH w/GPT and tie into a pert log. Find fluid level at 3,077'. Ran a correlation log from perf depth to 100' above pert depth. Send to town. POOH. Arm gun. RIH w/ 2-3/8" x 10' HC, 6 spf, 60 deg phase and tie into GPT log. Run correlation log and send to town. Get ok to pert from 4,140' to 4,150' with 265 psi on tubing. Spot and fired gun with 265.9 psi. After 5 min - 266.5 psi, 10 min - 267.5 psi and 15 min - 268.2 psi. POOH. All shots fired and gun was wet. Rig down lubricator and turn well over to field. TP - 271.1. H Nilm"n Aln"kn. LLC. RIB: MSL =107 TD =10,527 MD/ 9,885' TVD PBTD = 4,355' ND/ 3,843' TVD SCHEMATIC CASING DETAIL Kenai Gas Field Well: KDU 02 Last Completed: 8/21/1968 PTD: 168-049 Size Type Wt/Grade/Conn I ID Top Btm 20" Conductor N/A 3 Surf 58' 13-3/8' Surface 54.5/J-55/STC 12.615 Surf 1,317' 9-5/8" Intermediate 40/N-80/Seal Lock 8.835 Surf 6,027' 7" Liner 29 / N-80 / BTC 6.184 1 5,821' 10,522' TUBING DETAIL 3-1/2" Tubing 9.2/ N-80/ Butt Mod 1 2.992 1 Surf 2,085' JEWELRY DETAIL No Depth Item 1 4,370' Posiset Plug 2 5,007' Cement Retainer 3 5,385' Cement Retainer 4 5,921' Cement Retainer 5 7,861' Cement Retainer 6 9,325' Cement Retainer 7 9'sw Baker Packer 8 9,744' Junk Retainer 9 9,750' Cement Retainer 10 9,950' Cement Retainer 11 10,436' Junk Retainer 12 10,477' Cement Retainer ACTIVE PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) (Np) FT Date Status eding A8 4,140' 4,150' 3,659' 3,668' 1 10 1 1/28/2020 Open srling All 4,310' 4,350' 3,804' 3,839' 40 4/28/2016 Open erling Bl 4,380' 4,420' 3,865' 3,900' 1 30' 1 3/30/2016 1 Isolated ISOLATED PERFORATION DETAIL OPEN HOLE / CEMENT DETAIL 13-3/8" 1 Cmt w/ 650 sks of class "G" 9-5/8" Cmt w/ 700 sks of Gass "G" through shoe& w/ 300 sks thru DV tool @1918' 7" Cmt w/ 1000 AS of class "G" Updated by DMA 02-03-20 5,119' 1 5,120' 4,538' 4,539' 1' 5/17/2013 Squeezed 5,128' 5,138' 4,546' 4,556' 30' 5/17/2013 Squeezed ding Pool 6 5,170' 1 5,190' 4,586' 4,605' 20' 5/17/2013 Squeezed 5,235' 5,265' 4,648' 4,676' 30' 5/17/2013 Squeezed IT/72-8 7,911' 7,951' 7,276' 7,280' 40 3/18/1996 Squeezed IT/73-1 7,973' 7,992' 7,338' 7,357' 19 3/18/1996 Squeezed IT/75-8 8,220' 8,262' 7,584' 7,626' 42 11/29/1995 Squeezed per Ty/Bel 8,245' 8,255' 7,609' 7,618' 10' Nov -95 Squeezed 9,510' 9,522' 8,874' 8,886' 12' 8/13/1968 Isolated 9,558' 9,588' 8,922' 8,952' 30' Tyonek 9,854' 9,874' 9,218' 9,238' 20' Squeezed / Isolated 9.884 9,910' 9,248' 9,274' 26' 8/4/1974 9,919' 9,920' 9,283' 9,284' 1' 10,006' 10,007' 9,370' 9,371' 1' 7/27/1974 (8/8/1974) 10,028' 10,036' 9,392' 9,400' 8' 8/13/1968 10,080' 10,092' 9,443' 1 9,455' 12' 8/13/1968 OPEN HOLE / CEMENT DETAIL 13-3/8" 1 Cmt w/ 650 sks of class "G" 9-5/8" Cmt w/ 700 sks of Gass "G" through shoe& w/ 300 sks thru DV tool @1918' 7" Cmt w/ 1000 AS of class "G" Updated by DMA 02-03-20 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Kenai Gas Field, Sterling 3 Gas, Kenai Deep Unit 2(21-8) Permit to Drill Number: 168-049 Sundry Number: 319-578 Dear Mr. York: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.alaskc.gov Enclosed is the approved application for the 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, �A ssiT� eL. C ielowski Commissioner DATED this %$ day of December, 2019. IBDMStwl JAN 0 2 2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 nnr oa oan RE C 1EI DEC 18 2019 A GCC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate Q I Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casin 9 ❑ Other: N2 ❑ 2. Operator Name: Hilcorp Alaska, LLC 4. Current Well Class: 5. Permit to Drill Number: . f r ow 7C Exploratory ❑ Development Q 168-049 3. Address: 3800 Centerpoint Drive, Suite 1400 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, Alaska 99503 50-133-20121-00 — 00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 510A . Will planned perforations require a spacing exception? Yes ❑ No Q Kenai Deep Unit 2(21-8) ' 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028142 Kenai Gas Field / Sterling 3 Gas it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10,522' 9,885' 5,007' 4,433' -146 5,007' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 58' 20" 58' 58' Surface 1,317' 13-3/8" 1,317' 1,291' 2,730psi 1,130psi Intermediate 6,027' 9-5/8" 6,027' 5,418' 5,750psi 3,09opsi Production Liner 4,701' 7" 1 10,522' 1 9,898' 1 8,160psi 7,020psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 3-1/2" 9.2# / N-80 2,085' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A; NIA N/A; N/A 12. Attachments: Proposal Summary ✓ Wellbore schematic F1 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Strati ra hic 9 p ❑ Development Service ❑ 14. Estimated Date for 15. Well Status after proposed work: December 23rd, 2019 OIL ❑ WINJ ❑ WL Commencing Operations: ❑ DSP Suspended ❑ 16. Verbal Approval: Date: GAS Q WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Christina Twogood Authorized Name: Bo York 777-8345 Contact Email: ctwogood@hileorp.com Authorized Title: Operations Manager Contact Phone: 777-8443 6 Authorized Signatu Date: 71 L"- ?-A k % COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: I Test ❑ mechanical Integrity Test E) Location Clearance ❑ Plug Integrity❑j/�� I `BOP Other � i ci c. Ker le -SS �Uh�)n I 4 , �Tr � C��!"a ✓'`G� V `� �a � "1 -�-5� l fh,Ax� �l J Post Initial Injection MIT Req'd? Yes No 0 /'yu Spacing Exception Required? Yes E] No CRISubsequentForm Required: C ® "' (.d l 3BDMS®. JAN 0 2 2020 ` APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Z . 43 —� 5 Submff Form and Form 1 3 Revised 1112015 tY+ pproved applieati�n s�ir� IG2�rr{prjr)k r the date of approval. /�(� Ary chm in ,p Atte q (19 II K Ililmm Alaska, LL Well Prognosis Well: KDU 02 Date:12/11/2019 Well Name: KDU 02 API Number: 50-133-20121-00-00 Current Status: Shut -In Gas Producer Leg: N/A Estimated Start Date: December 23rd, 2019 Rig: E -Line Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 168-049 First Call Engineer: Christina Twogood (907) 777-8443 (907) 378-7323 (C) Second Call Engineer: Ted Kramer (907) 777-8420 (985) 867-0665 (C) AFE Number: Current BHP: Max. Expected BHP: Max. Potential Surface Pressure: Brief Well Summary "' 250 psi @ 3,804' TVD — 530 psi @ 3,839' TVD "' 146 psi (Calculated from offset well KU 11-08 Static BHP Survey on 3/7/2013) (Based on offset well RFT data from 04/04/2017) (Based on expected BHP and gas gradient to surface (0.10psi/ft)) In 1968, KDU 02 was drilled and completed in the Tyonek D. It was perforated in the D4D and D413 as well as the D3C (strong water drive sand). It was completed up -hole in the Upper Tyonek in 1995; eventually being recompleted to the Beluga and Sterling. The well was shut-in in 2013. The purpose of this work/sundry is to add perforations in Sterling A8 and A10 sands. Notes Regarding Wellbore Condition • The well is currently shut-in. • Minimum ID is 2.992". • Last tag @ 4,817' KB w/ 2.5" Centralizer and 1.75" Sample Bailer on 4/16/2016. Safety Concerns r2 .tom Z�f� • Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. • Consider tank placement based on wind direction and current weather forecast (venting nitrogen during this job). • Ensure all crews are aware of stop job authority. E -Line Procedure 1. MIRU E -Line and pressure control equipment. PT lubricator to 250 psi Low/ 2,000 psi High. 2. RIH with GPT tool and find fluid level. If fluid is over the depth of the new perfs, discuss using Nitrogen with the Operations Engineer. 3. If needed, RU Nitrogen Truck, pressure up on well and push water back into formation. Use GPT tool to confirm water level is below interval to pert. B tlikera Alaska, LL 4. RU perfguns. 5. RIH and perforate the following interval: Well Prognosis Well: KDU 02 Date:12/11/2019 Zone Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Sterling A8 +4,140' +4,150' +3,659' +3,668' +10' Sterling A10 +4,226' +4,231' +3,734' +3,736' +5' a. Discuss with Operations Engineer pressuring up well to 400 psi before perforating. b. Proposed perfs also shown on the proposed schematic in red font. c. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. d. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. e. Use Gamma/CCL to correlate. f. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. g. All perforations in table above are located in the Sterling 3 Gas Pool based on Conservation Order No. 510A. 6. POOH. 7. RD a -line. 8. Turn well over to production. (Test SSV with -in 5 days of stable production on well — notify AOGCC 24hrs before testing) T, E -line Procedure (Contingency) 1. If any zone produces sand and/or water or needs isolated: _11 4, l( 3 / �; n �� R fir/ 2. MIRU E -Line and pressure control equipment. PT lubricator to 250 psi Low/ 3,500 psi High. % 3. RIH and set 3-1/2" Casing Patch or set 3-1/2" CIBP above the zone and dump 35' of cement on top ` of the plug. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Standard Well Procedure — N2 Operations Kenai Gas Field SCHEMATIC Well: KDU 02 Last Completed: 8/21/1968 Hilcarp Alaska, LLC PTD: 168-049 RIB: MSL=107 �s1 TOC@4,355' TOC@ 5,754 -_.I` ', CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 20" Conductor N/A 5,128' Surf 58' 13-3/8' Surface 54.5/1-55/STC 12.615 Surf 1,317' 9-5/8" Intermediate 40/N-80/Seal Lock 8.835 Surf 6,027' 7" Liner 29/N-80/BTC 6.184 5,821' 10,522' TUBING DETAIL 3-1/2" Tubing 9.2 / N-80/ ButtMod 1 2.992 1 Surf 2,085' JEWELRY DETAIL TD=10,522' PBTD=10,477' NoUCementRetainer Top(MD) Btm (MD) Item 1Posiset Date Status Plug 2Cement (Btm Retainer3Cement 5,128' Sterling All Retainer4Cement 3,804' 3,839' 40 Retainer5Cement Sterling B1 4,380' 4,420' Retainer6ement 40 3/30/2016 Isolated Retainer7Baker 20' Packer 8 9,744' Junk Retainer 9 9,750' Cement Retainer 30 9,950' Cement Retainer 11 10,436' Junk Retainer 12 10,477' Cement Retainer ACTIVE PERFORATION DFTAII Sands Top(MD) Btm (MD) Top (TVD) FT Date Status 1' 5/17/2013 (Btm Sterling Pool 5,128' Sterling All 4,310' 4,350' 3,804' 3,839' 40 4/28/2016 Open Sterling B1 4,380' 4,420' 3,865' 3,900' 40 3/30/2016 Isolated LSOI ATM DFRIPOPATIr1Al nFTAII OPEN HOLE / CEMENT DETAIL 13-3/8" Cmt w/ 650 sks of class "G" 9-5/8" Cmt w/ 700 sks of class "G" through shoe& w/300 sks thru OV tool @ 1918' 7" Cmt w/ 1000 sks of class "G" Updated by DMA 05-02-16 5,119' 5,120 4,538' 4,539' 1' 5/17/2013 Squeezed Sterling Pool 5,128' 5,138' 4,546' 4,556' 10' 5/17/2013 Squeezed 5,170' 5,190' 4,586' 4,605' 20' Squeezed 5,235' 5,265' 4,648' 4,676' 30' Squeezed UT/72-8 7,911' 7,951' 7,276' 7,280' 40 w"/126 Squeezed UT/73-1 7,973' 7,992' 7,338' 7,357' 19 Squeezed UT/75-8 8,220' 8,262' 7,584' 7,626' 42 11/29/1995 Squeezed Upper Ty/Bel 8,245' 8,255' 7,609' 7,618' 10' Nov -95 Squeezed 91510' 91522' 81874' 8,886' 12' Isolated 9,558' 9,588' 8,922' 8,952' 30' 8/13/1968 9,854' 9,874' 9,218' 9,238' 20' Squeezed / Tyonek 9,884' 9,910' 9,248' 97274' 26' 8/4/1974 9,919' 9,920' 9,283' 9,284' V 10,006' 10,007' 9,370' 9,371' 1' 7/27/1974 Isolated 10,028' 10,036' 9,392' 9,400' 8' 8/13/1968 (8/8/1974) 10,080' 10,092' 9,443' 9,455' 12' 8/13/1968 OPEN HOLE / CEMENT DETAIL 13-3/8" Cmt w/ 650 sks of class "G" 9-5/8" Cmt w/ 700 sks of class "G" through shoe& w/300 sks thru OV tool @ 1918' 7" Cmt w/ 1000 sks of class "G" Updated by DMA 05-02-16 R cora Alaska, LLf. RKB: MSL =107 o 13-3/9'4 TOC@4,355' TOC@ 5,750 L'? Cc Ca 7,! TOF Tc 8,437 PROPOSED SCHEMATIC CASING DETAIL. Kenai Gas Field Well: KDU 02 Last Completed: 8/21/1968 PTD: 168-049 I TUBING DETAIL IM 3-1/2" Tubing 9.2/N-80/Butt Mod 2.992 Surt 2,085' JEWELRY DETAIL 8 TD=10,522' PBTD=10,477 No Size Type Wt/Grade/Conn ID Top Btm 20" Conductor N/A Surf 58' 13-3/8' Surface 54.5/J-55/STC 12.615 Surf 1,317' 9-5/8" Intermediate 40/N-80/Seal Lock 8.835 Surf 6,027' 7" Liner 29/N-80/BTC 6.184 5,821' 10,522' I TUBING DETAIL IM 3-1/2" Tubing 9.2/N-80/Butt Mod 2.992 Surt 2,085' JEWELRY DETAIL 8 TD=10,522' PBTD=10,477 No Depth Item 1 4,370' Posiset Plug 2 5,007' Cement Retainer 3 5,385' Cement Retainer 4 5,921' Cement Retainer 5 7,861' Cement Retainer 6 9,325' Cement Retainer 7 9,500' Baker Packer 8 9,744' Junk Retainer 9 9,750' Cement Retainer 10 9,950' Cement Retainer 31 10,436' Junk Retainer 12 10,477' Cement Retainer ACTIVE PERFnRATinm r1FTA6 Sands (MD)W4,350' 5,120' Top (TVD) (TVD) FT Date Status Sterling AB Sterling AlO226' 140, ;4,310- 5,138' ±3,659' ±3,734' ±3,668' ±3,736' 10 S TBD TBD Proposed Proposed Sterling All 5,170' 5,190' 3,804' 3,839' 40 4/28/201Sterling Squeezed Bl 80' 5,265' 7,951' 7,992' 8,262' 3,865' 3,900' 40 3/30/2016 Isolated Igr)l ATM DF0FnDAT1na1 ncTAu OPEN HOLE / CEMENT DETAIL 13-3/8" Cmt w/ 650 sks of class "G" 9-5/8" 1 Cmt w/ 700 sks of class "G" through shoe& w/ 300 sks thru DV tool @1918' 7" 1 Cmt w/ 1000 sks of class "G" Updated by TRH 12-10-2019 5,119' 5,120' 4,538' 4,539 - 1' 5/17/2013 Squeezed Sterling Pool 5,128' 5,138' 4,546' 4,556' 10'5/17/2013 Squeezed 5,170' 5,190' 4,586' 4,605' 20' 5/17/2013 Squeezed UT/72-8 UT/73-1 UT/75-8 5,235' 7,911' 7,973' 8,220' 5,265' 7,951' 7,992' 8,262' 4,648' 7,276' 7,338' 7,584' 4,676' 7,280' 7,357' 7,626' 30' 40 19 42 5/17/2013 3/18/1996 3/18/1996 11/29/1995 Squeezed Squeezed Squeezed Squeezed Upper Ty/Bel 8,245' 8,255' 7,609' 7,618' 10' Nov -95 Squeezed 91510' 91522' 81874' 81886' 12' Isolated 9,558' 9,588' 8,922' 8,952' 30' 8/13/1968 Tyonek 9,854' 9,874' 9,218' 9,238' 20' Squeezed/ 9'894' 91910' 9,248' 9,274' 26' 8/4/1974 9,919' 9,920' 9,283' 9,284' 1' 10,006' 10,007' 9,370' 9,371' 1' 7/27/1974 Isolated 10,028' 10,036' 9,392' 9,400' 8' 8/13/1968 (8/8/1974) 10,080' 10,092' 9,443' 9,455' 12' 8/13/1968 OPEN HOLE / CEMENT DETAIL 13-3/8" Cmt w/ 650 sks of class "G" 9-5/8" 1 Cmt w/ 700 sks of class "G" through shoe& w/ 300 sks thru DV tool @1918' 7" 1 Cmt w/ 1000 sks of class "G" Updated by TRH 12-10-2019 STANDARD WELL PROCEDURE Iilcorli:lla.ka,LdA.. NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre -job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4 -gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL vl Page 1 of 1 Schwartz, Guy L (CED) From: Christina Twogood - (C) <ctwogood@hilcorp.com> Sent: Friday, December 20, 2019 11:36 AM To: Schwartz, Guy L (CED) Cc: Ted Kramer; Donna Ambruz Subject: RE: [EXTERNAL] KDU 2 (21-8) (PTD 168-049) Perfsundry application. Guy, The 2016 perforations in the Sterling B1 and A11 sands were non-productive in KDU-02. For the current sundry request, Hilcorp respectfully requests a variance from 20 AAC 25.200 for requiring a packer for tubing -casing annulus isolation for the test of the A8 and A10 sands. Hilcorp is requesting up to 30 days to test through the kill string to test the low pressure reserve possibly remaining. Plans for permanent production operations will be submitted based on results of this test. Thank you, Christina Twogood Operations Engineer Kenai Asset Team, Hilcorp Alaska 3800 Centerpoint Dr., Anchorage, AK 99503 (w) 907-777-8443 (c) 907-378-7323 From: Schwartz, Guy L (CED) [mailto:guy.schwartz@alaska.gov] Sent: Thursday, December 19, 2019 2:44 PM To: Ted Kramer <tkramer@hilcorp.com>; Christina Twogood - (C) <ctwogood@hilcorp.com> Subject: [EXTERNAL] KDU 2 (21-8) (PTD 168-049) Perfsundry application. Can you guys look at the previous sundry when it was perforated in 2016. This well does not have a packer. Include the results of that in the well history. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guv.schwartz@alaska.aov). The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, • • Carlisle, Samantha J (DOA) From: Schwartz, Guy L(DOA) Sent: Wednesday, February 22, 2017 9:12 AM To: Donna Ambruz Cc: Chad Helgeson;Taylor Nasse;Carlisle, Samantha J (DOA) Subject: RE: Sundry Cancellation - Sundry#316-106 KDU 2 (21-8) (PTD 168-049) Donna, Sundry#316-106 will be withdrawn as requested. Guy Schwartz Sr. Petroleum Engineer ED MAR £ 4 iL AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Donna Ambruz [mailto:dambruz@hilcorp.com] Sent:Tuesday, February 21, 2017 3:14 PM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc:Chad Helgeson<chelgeson@hilcorp.com>;Taylor Nasse<tnasse@hilcorp.com> Subject:Sundry Cancellation-Sundry#316-106 KDU 2 (21-8) (PTD 168-049) Guy, Please withdraw the above mentioned sundry. Thank you. Dannac andouvz Operations/Regulatory Tech Kenai Asset Team Hilcorp Alaska, LLC 3800 Centerpoint Drive,Suite 1400 Anchorage,AK 99503 907.777.8305-Direct 907.777.8310-Fax dambruz@hilcorp.com 1 "e RBD d iS �v `;:;`' — 9 I STATE OF ALASKA RECEIVED ALA"OIL AND GAS CONSERVATION COM.SION MAY 3 1 2016 REPORT OF SUNDRY WELL OPERATIONS AOGC( 1.Operations Abandon U Plug Perforations j47) Fracture Stimulate ❑ Pull Tubing LJ Operations shutdown __I Performed: Suspend ❑ Perforate ❑✓ Other Stimulate [ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ ?rforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑✓ Other: CT N2 Jetting+Flow Test ❑✓ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Exploratory DevelopmentEx ❑ p ry ❑ 168-049 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-133-20121 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028142 Kenai Deep Unit 2(21-8) 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kenai Field/Beluga-Upper Tyonek&Sterling 6 Gas 11.Present Well Condition Summary: Total Depth measured 10,522 feet Plugs measured 5,007 feet true vertical 9,885 feet Junk measured N/A feet Effective Depth measured 5,007 feet Packer measured 9,500 feet true vertical 4,433 feet true vertical 8,864' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 58' 20" 58' 58' Surface 1,317' 13-3/8" 1,317' 1,291' 2,730psi 1,130psi Intermediate 6,027' 9-5/8" 6,026' 5,418' 5,750psi 3,090psi Production Liner 4,701' 7" 10,522' 9,898' 8,160psi 7,020psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic SCPOE° JUN 1 6 2016'. Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/N-80 2,085' 1,955' Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 25 Subsequent to operation: 0 0 0 0 16 14.Attachments(required per 20 AAC 25.070.25.071,&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 RI WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ 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: 316-185 Contact Taylor Nasse-777-8354 Email tnasse(C�hiIcorp.com Printed Name Chad Helgeson Title Operations Manager Signature ';‘.,:„./h/•"..., Phone 907-777-8405 Date 513'06 � 6•/1/4- Form 10-404 Revised 5/2015 � RBDMS �,�/ Submit Original Only �7 /� JUN 0 2 2016 • • IIH i lcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date KDU-02 50-133-20541-00 204-107 3/22/16 4/27/16 Daily Operations: 03/22/2016-Tuesday Obtain permit. Hold JSA and safety meeting. Discuss job procedures. MIRU SLB CTU 12. Start BOPE test. Test all rams and valves to 250/4,500 psi. Witness waived by Jim Regg, AOGCC. Perform accumulator draw down test. BOPE test good. 03/23/2016-Wednesday Obtain PTW. Hold safety meeting. Pick injector. Make up 2.25" CC. Stab on well pressure test lubricator to 250/4,500 psi. RIH pressure building from coil displacement. Open choke. Tag at 4,907'. Pick up and re tag at same depth 3 times. Pump down CT with closed choke to pressure test casing. Start 30 minute pressure test. Starting time 1032 @ 2,701 psi. End pressure test at 1102 @ 2,679 psi. 22 psi loss over 30 minutes. Good test OOA pressure or 13-3/8" by 9-5/8" started at 17 psi and ended at 22 psi. No communication between pipe annuli. Send graph to town for records. Cooling down N2. Open well to take returns. PT N2 lines to 250/4,500 psi. Good test. Open up to coil. Pumping 1,800 scf/min. Increased to 2,500 scf/min. Vac truck load straps are 373 bbls returned. SLB straps during job are 400 bbls returned. Well bore blowing dry. Start POOH to surface. Shut in well head. Tagged up at surface. 500 psi on wellhead. 373-400 bbls returned from well bore. 376,000 scf pumped. Or 4,050 gallons of N2. Rig down CTU 12. 03/29/2016-Tuesday Meet at office. Mobe to location. PTW and JSA. Talked about the dangers of well being pressured up by N2. Rig up lubricator and pressure test to 250 psi low and 1,500 psi high.TP- 646 psi. RIH w/2.5" x 12' Shogun spiral strip gun, 4 spf/60 deg phase and tie into partial log sent by Taylor. Bleed well down to 30.1 psi. Ran correlation log and send to town. Get ok to perf from 4,408'to 4,420'. Fired gun with 30.1 psi and went to 33.5 psi after five minutes. Got hung up coming thru tubing tail. Set jars off and tools came free. Got out of hole and 12' of the strip gun was gone. Tools were dry. RIH with 2.5" OD firing head to check and see it strip was in tubing tail. Went down to 4,600' with no problem. POOH. RIH w/2.5" x 13'Shogun spiral strip gun,4 spf/60 deg phase and tie into partial log sent by Taylor. Ran correlation log and send to town. Get ok to perf from 4,395'to 42408.Fired gun with 34.6 psi and went to 35.2 psi after five minutes. Got all tools back.Tools were dry. All shots fired RIH w/2.5" x 15' Shogun spiral strip gun,4 spf/60 deg phase and tie into partial log sent by Taylor. Ran correlation log and send to town. Get ok to perf from 4,380'to 4,395'. Fired gun with 36.3 psi and went to 36.9 psi after five minutes. Got all tools back.Tools were dry. All shots fired.TP was still 36.9 psi when swab was shut. Rig down lubricator and turn well over to field. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date KDU-02 50-133-20541-00 204-107 3/22/16 4/27/16 Daily Operations: 04/20/2016-Wednesday Meet at office. Mobe to location. PTW and JSA. Spot equipment. Rig up lubricator and pressure test to 250 psi low and 1,500 psi high.TP- 147 psi. Decided to run SLB GPT tools because SLB wasn't real comfortable tying in with the CCL log we had because you cannot run gamma ray with PosiSet plug,just the CCL. Plus make sure we knew where fluid level was. RIH with SLB press/temp/gamma ray/CCL tool and got a good log. Found fluid level at top of B-1 perf at 4,380'. POOH. RIH w/PosiSet plug and run correlation log and send to town. Get ok to set plug at 4,370'. Spotted plug and started the setting process. After 3 hours decided plug was not going to shear. Got ok to mechanically shear tool. Shear tool and came out of hole. Setting tool looked like a good set.TP- 147 psi Make up cement dump bailer. Fill with water and went down hole and attempted to dump water on top of plug.Troubleshoot bailer and make couple more attempts to dump bail water without success.Shut down for the night and SLB will talk to their people about problem. Rig for stand by. 04/21/2016-Thursday PTW and JSA. Made 3 attempts to dump bail with SLB positive displacement bailer. Got 1 out of 3 to dump cement on top of plug at 4,370'.Troubleshoot bailer but could not pin down problem. Will rent Pollard E-line top fill explosive bailer to use tomorrow. Rig down for stand by. 04/22/2016- Friday PTW and JSA SLB got permission to use Pollard E-Line dump bailer. Chased stray voltage from around 1300 to 1730 hrs. Had no stray voltage when grounded but too much when not grounded (0.33 volts). Got ok to use bailer with the ungrounded stray voltage. Make up 2.5" x 30' dump bailer filled with cement and could not get thru swab valve. Cycled valve a few times and got it to go thru swab valve. Bailer was bent just a little bit which would hang up. RIH with bailer and dump bailed cement on top of plug at 4,370'. Made 4 runs of cement today which makes it a total of 5 runs. SLB crew was tired so I sent them home. We'd like 2 more runs and they will be back around 10 AM to finish the other two runs. Rig for standby. 04/23/2016-Saturday PTW and JSA, mobe to location. RIH w/2.5" x 30' bailer full of cement and dump bail cement on top of plug 4,370'. Made 2 runs which put total cement of 10.6' on top of plug. Cement in place at 1315 hrs. Est top of cement at 4,369.5'. Est top of shear rod 4,368.5' (gets left in hole when you have to pull off plug to release it). Rig down lubricator and wait on cement. Cement samples are in Mike's office. 0 • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date KDU-02 50-133-20541-00 204-107 3/22/16 4/27/16 Daily Operations: 04/27/2016-Wednesday SIMOPS, PTW and JSA. Mobe to location. Rig up lubricator. PT to 250 psi low and 1,500 psi high. RIH with 2-1/2" x 16' Spiral Strip gun,4 spf, 60 deg phase, tie into Pollard GPT tool dated 4-20-1 and tag bottom at 4,355'. Run correlation log and send to town. Get ok to perforate from 4,334' to 4,350'. Fired gun with 110 psi on well. Pull out of hole and left 16' of the strip in hole. Had good indication of gun going off. Had 130 psi on tubing. All shots fired RIH with 2-1/2" x 14', Spiral Strip gun, 4 spf, 60 deg phase, tie into Pollard GPT tool dated 4-20-1 and tag bottom at 4,355'. Run correlation log and send to town. Get ok to perforate from 4,320'to 4,334'. Fired gun with 140 psi on well. Had good indication of gun going off.All shots fired. RIH with 2-1/2" x 10', Spiral Strip gun,4 spf, 60 deg phase, tie into Pollard GPT tool dated 4-20-1 and tag bottom at 4,355'. Run correlation log and send to town. Get ok to perforate from 4,310' to 4,320'. Fired gun with 140 psi on well. Had good indication of gun going off, all shots fired. Rig down lubricator and turn well over to field. .. .11 • • Kenai Gas Field SCHEMATIC Well: KDU 02 Last Completed: 8/21/1968 Hilcorp Alaska,LLC PTD: 168-049 CASING DETAIL RKB:MSL=107' Size Type Wt/Grade/Conn ID Top Btm 20"J l 20" Conductor N/A Surf 58' 13-3/8' Surface 54.5/J-55/STC 12.615 Surf 1,317' 9-5/8" Intermediate 40/N-80/Seal Lock 8.835 Surf 6,027' 7" Liner 29/N-80/BTC 6.184 5,821' 10,522' TUBING DETAIL 3-1/2" Tubing 9.2/N-80/Butt Mod 2.992 Surf 2,085' 13-3/8"a • • JEWELRY DETAIL No Depth Item 1 4,370' Posiset Plug TOC@4,355'-� All 2 5,007' Cement Retainer ---__.� B1 1 3 5,385' Cement Retainer 4 5,921' Cement Retainer r 2 5 7,861' Cement Retainer 6 9,325' Cement Retainer TOC@ 5,750' "` ' • 3 7 9,500' Baker Packer *, 8 9,744' Junk Retainer 9-5/8" ,'• 4 9 9,750' Cement Retainer 10 9,950' Cement Retainer 11 10,436' Junk Retainer 4 12 10,477' Cement Retainer ACTIVE PERFORATION DETAIL BtM Sands Top(MD) Btm(MD) Top(TVD) (TVD) FT Date Status Sterling All 4,310' 4,350' 3,804' 3,839' 40 4/28/2016 . Open Sterling B1 4,380' 4,420' 3,865' 3,900' 40 3/30/2016 Isolated ISOLATED PERFORATION DETAIL Retainer@ 7,861' 5,119' 5,120' 4,538' 4,539' 1' 5/17/2013 Squeezed is 5 lig 5,128' 5,138' 4,546' 4,556' 10' 5/17/2013 Squeezed Collaps ed Sterling Pool 6 5,170' 5,190' 4,586' 4,605' 20' 5/17/2013 Squeezed Casing@ 5,235' 5,265' 4,648' 4,676' 30' 5/17/2013 Squeezed 7,931' UT/72-8 7,911' 7,951' 7,276' 7,280' 40 3/18/1996 Squeezed UT/73-1 7,973' 7,992' 7,338' 7,357' 19 3/18/1996 Squeezed UT/75-8 8,220' 8,262' 7,584' 7,626' 42 11/29/1995 Squeezed Upper Ty/Bel 8,245' 8,255' 7,609' 7,618' 10' Nov-95 Squeezed 9,510' 9,522' 8,874' 8,886' 12' 8/13/1968 Isolated 9,558' 9,588' 8,922' 8,952' 30' 9,854' 9,874' 9,218' 9,238' 20' 9,884' 9,910' 9,248' 9,274' 26' 8/4/1974 Squeezed Tyonek 9,919' 9,920' 9,283' 9,284' 1' 10,006' 10,007' 9,370' 9,371' 1' 7/27/1974 10,028' 10,036' 9,392' 9,400' 8' 8/13/1968 Isolated 10,080' 10,092' 9,443' 9,455' 12' 8/13/1968 TOF Tagged @ 8,432'-10/15/2010 RS`�, 5-11 OPEN HOLE/CEMENT DETAIL 13-3/8" Cmt w/650 sks of class"G" 9-5/8" Cmt w/700 sks of class"G"through shoe&w/300 sks thru DV tool @1918' 7" Cmt w/1000 sks of class"G" TD=10,522' PBTD=10,477' Updated by DMA 05-02-16 6'S.- 04-k11 C Seth Nolan Hilcorp Alaska, 2, �� GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Co Tele: 907 777-8308 Itilrnrp:tI kp,LL( Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATA LOGGED S 21/201(, o K.BENDER DATE 05/17/16 To: Alaska Oil & Gas Conservation Commission RECEIVED Makana Bender Natural Resource Technician II 14012 0 2016 333 W 7th Ave Ste 100 Anchorage, AK AOGCC 99501 DATA TRANSMITTAL KDU 2(21-8) Plug setting record prints and digital data Prints: Posiset Plug Setting Record/ Pressure Temperature Log (MPBT/GR/CCL/PRESS/TEMP) CD1: Elog digital data DLIS Data LAS Data Lcg Please include current contact information if different from above. SCplitED JUN 1 3 2016 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Receivedy:✓ ,��y Date: V OF T�� • ID THE STATE Alaska Oil and Gas ofLAS <:A Conservation Commission A 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS1`14' Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400CANN ' ( 11 Anchorage, AK 99503 Re: Kenai Gas Field, Beluga-Upper Tyonek& Sterling 6 Gas, Kenai Deep Unit 2 (21-8) Permit to Drill Number: 168-049 Sundry Number: 316-185 Dear Mr. Helgeson: 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, Cathy . Foerster Chair DATED this ) Tay of March, 2016. RBDMS 1'V MAR 2 1 2016 • • RECEIVED STATE OF ALASKA MAR 0 9 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION ors' g/6//4 APPLICATION FOR SUNDRY APPROVALS AO C j 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑� Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well El - Alter Casing ❑ Other: CT N2 Jetting lib 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: r e.. . Hilcorp Alaska,LLC Exploratory ❑ Development El- 168-049 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic El Service El 6.API Number. Anchorage,Alaska 99503 50-133-20121-00 ' 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 510A Kenai Deep Unit 2(21-8) Will planned perforations require a spacing exception? Yes ❑ No LI 9.Property Designation(Lease Number): 10. Field/Pool(s): FEDA028142 Kenai Gas Field/Beluga-Upper Tyonek&Sterling 6 Gas 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): 10,522' • 9,885' • 5,007' 4,433' 1,287psi 5,007' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 58' 20" 58' 58' Surface 1,317' 13-3/8" 1,317' 1,291' 2,730psi 1,130psi Intermediate 6,027' 9-5/8" 6,027' 5,418' 5,750psi 3,090psi Production Liner 4,701' 7" 10,522' 9,898' 8,160psi 7,020psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: ic.U Sr,-:7 Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.2#/N-80 2,085' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A;N/A "'404.-ril- N/A; N/A 12.Attachments: Proposal Summary ❑ Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic 1 ] Development ❑✓ Service ❑ 14. Estimated Date for 15.Well Status after proposed work: CommencingOperations: March 23,2016 OIL WINJ WDSPL p ❑ ❑ ❑ Suspended ❑ 16.Verbal Approval: Date: GAS H - 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. Contact Taylor Nasse-777-8354 Email tnasse( hilcorricom Printed Name Chad Helgeson Title Operations Manager f Signature //..1/2/7.1 "/ :: Phone 907-777-8405 Date 3/`(l/C., COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. r ` Plug Integrity ❑ BOP Test IX' Mechanical Integrity Test Li Location Clearance Other: k 4•15-41, fp`a + &J P (c.71--u, *-- L',,c4e,„-kf.;s- eo nv)it...4=-1...d ?pre,v e....06/,-.4$4) Litii ro.,,,--- ''"e-( 3.—:::: i m-20 s . Post Initial Injection MIT Req'd? Yes ❑ No El //, ��e� Spacing Exception Required? Yes ❑ No d Subsequent Form Required: I,, L!V - RBDMS (rV MAR 2 2016 APPROVED BY Approved by: ; COMMISSIONER THE COMMISSION Date:3—/6 _ 4 "I ,7. 111-I( Submit Form and Form 10-403 Revised 11/2015 oIed ppliCatlo f lid for�Z months from the date of approval. Attachments in Quplicate • • Well Prognosis Well: KDU-02 Hilcorp Alaska,LL Date:02/09/2016 Well Name: KDU-02 API Number: 50-133-20121-00 Current Status: Suspended Gas Well Leg: N/A Estimated Start Date: 03/23/16 Rig: Reg.Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 168-049 First Call Engineer: Taylor Nasse (907)777-8354 (0) (907)903-0341 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) AFE Number: Current Surface Pressure: 0 psi Maximum Expected BHP: — 1,677 psi @ 3,900' TVD (Assumed 0.43 psi/ft gradient) Max. Potential Surface Pressure: — 1,287 psi (Assumed 0.10 psi/ft gas gradient) Brief Well Summary y -_ 3( .—IO ' KDU-02 was drilled as a grassroots well to target gas sands in the Tyonek formations. Hilcorp Alaska previously attempted to re-enter the well to test additional deep Tyonek sands but found multiple tight casing locations - and temporarily suspended the well with a 3-1/2" kill string in the well. The purpose of this work/sundry is to determine if the B1 and All sands have any depleted gas remaining. These sands were shut-in by the previous operator at 65 psi flowing pressure. If these zones can be tested to show that they still have producible reserves, Hilcorp will develop additional well work in the fielcl_to__a_cc,ess_ these low pressure sands. The work on this project is to jet the well dry with coiled tubing and perforate the - Sterling B1 and All sands. lance: Hilcorp Alaska respectfully requests a variance from 20 AAC 25.200 for requiring a packer for tubing- casing annulus isolation for the test of these sands. Hilcorp is requesting up to30 days to test through the kill string and-possib44,1p-tlarfwittltrs to test the low pressure reserves possibly remaining.A new workover sundry will be submitted for permaneAPeomprelion based on results of this test. 470 7 4 claw 5F s "19 � I Notes Regarding Wellbore Condition 3 6;44 • Tubing and casing are full of produced fluid. • Well and tubing will be drifted and tagged prior to starting work. • Pressure test 9-5/8" casing to 2,500 psi (monitor surface casing pressure during test). Safety Concerns • Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people - could enter, i.e. near flow-back tank (Coiled tubing work). • Consider tank placement based on wind direction and current weather forecast (venting nitrogen during this job) (Coiled tubing work) • Ensure all crews are aware of stop job authority(All crews) Coiled Tubing Procedure: 'A_ `� 2-5-0t;/a'F 1. Submit 24 hr. witness notification to AOGCC via web base notification. • • • Well Prognosis Well: KDU-02 Hilcoru Alaska,LL Date:02/09/2016 2. MIRU Coiled Tubing, PT BOPE to 250/4500 psi. 3. Isolate production flow line. Route well production to open top diffuser 400 bbl tank. 4. Pressure test N2 lines to 4,500 psi prior to starting job. 5. RIH w/jet nozzle BHA to 5,007' MD and tag PBTD. 6. PU 10ft and displace well fluids with Nitrogen. a. Estimated volume of displaced 6% KCI is 380 bbl. (Reverse N2 jet) 7. Leave well with +/- 150 psi nitrogen SITP. 8. POOH w/coil. LD jet nozzle BHA. 9. RD Coiled Tubing. E-Line Procedure 1. MIRU e-line and pressure control equipment. PT lubricator to 250 psi low/1,500 psi high. Note that the well is pressurized with nitrogen. a. If necessary, bleed nitrogen pressure down as requested by the RE to establish a drawdown on the formation (possible to bleed to 0 psi). 2. Perforate the Sterling sands with 2-3/8" 5 SPF 60 deg phased perf guns or 2.5" strip guns. All intervals are planned for 12 SPF so each zone may be shot twice. Send the correlation pass to Operations Engineer, Reservoir Engineer, and Geologist for confirmation. Gross Proposed Perforated Intervals s ' � �'' belt Sands Top (MD) Btm (MD) FT41- Sterling B1 ±4,380 ±4,420 ±40 .v Sterling All ±4,310 ±4,350 ±40 ✓ -144- 3. om3. POOH. 4. Individually flow each zone through test separator and record water and gas rates. 660c►r�"��If the B1 sand is not commercial or wet, the zone will be permanently plugged back with a Neo Wide `"'Range T-TBP. 6. RD e-line. .. u reS SSI/ 7. Turn well over to production./� © 3 o dam' / '-/ i end, , A e p+ „4- re_ Attachments: 4 Cerin ►�cri3�o� J 1. Actual Schematic 2. Proposed Schematic 3. Wellhead Diagram ,l �,r 4. CT BOPE Schematic 5. CT Schematic(forward and reverse jetting) 6. CBL of 9-5/8"casing showing cement above proposed perforations X , d(t / A /0 4 j4d, . � ° '- fhb J • Kenai Gas Field Well: KDU 02 • la 0 SCHEMATIC Last Completed: 8/21/1968 Hilcoru Alaska,LLC PTD: 168-049 CASING DETAIL RKB:MSL=107' Size Type Wt/Grade/Conn ID Top Btm 20" Conductor N/A Surf 58' 20" 13-3/8' Surface 54.5/J-55/STC 12.615 _ Surf 1,317' 9-5/8" Intermediate 40/N-80/Seal Lock 8.835 Surf 6,027' 7" Liner 29/N-80/BTC 6.184 5,821' 10,522' TUBING DETAIL 3-1/2" Tubing 9.2/N-80/Butt Mod 2.992 Surf 2,085' 13-3/8" JEWELRY DETAIL No Depth Item 1 5,007' Cement Retainer 2 5,385' Cement Retainer 3 5,921' Cement Retainer 4 7,861' Cement Retainer ' 1 5 9,325' Cement Retainer 6 9,500' Baker Packer TOC@5,750' �+E 2 7 9,744' Junk Retainer 8 9,750' Cement Retainer 9-5/8" 9 9,950' Cement Retainer 10 10,436' Junk Retainer 11 10,477' Cement Retainer 3 ACTIVE PERFORATION DETAIL Btm Sands Top(MD) Btm(MD) Top(TVD) (TVD) FT Date Status UT/72-8 7,911' 7,951' 7,276' 7,280' 40 Squeeze UT/73-1 7,973' 7,992' 7,338' 7,357' 19 3/18/1996 Squeeze UT/75-8 8,220' 8,262' 7,584' 7,626' 42 11/29/1995 Squeeze ISOLATED PERFORATION DETAIL Retainer@ 7,861' 5,119' 5,120' 4,538' 4,539' 1' I! -4 5,128' 5,138' 4,546' 4,556' 10' ;44, Sterling Pool 6 Collapsed r5,170' 5,190' 4,586' 4,605' 20' Nov-95 Squeezed Casing@ .. .T` 5,235' 5,265' 4,648' 4,676' 30' 7,931' Upper Ty/Bel 8,245' 8,255' 7,609' 7,618' 10' h 9,510' 9,522' 8,874' 8,886' 12' 8/13/1968 Isolated 9,558' 9,588' 8,922' 8,952' 30' 9,854' 9,874' 9,218' 9,238' 20' Tyonek 9,884' 9,910' 9,248' 9,274' 26' 8/4/1974 Squeezed - 9,919' 9,920' 9,283' 9,284' 1' 10,006' 10,007' 9,370' 9,371' 1' 7/27/1974 10,028' 10,036' 9,392' 9,400' 8' 8/13/1968 Isolated 10,080' 10,092' 9,443' 9,455' 12' 8/13/1968 OPEN HOLE/CEMENT DETAIL 13-3/8" Cmt w/650 sks of class"G" TOFTagged @ 9-5/8" Cmt w/700 sks of class"G"through shoe&w/300 sks thru DV tool @1918' 8,432'-10/15/2010 r 7" Cmt w/1000 sks of class"G" 5 TD=10,522' PBTD=10,477' Created By:TDF 5/28/2013 Kenai Gas Field PROPOSED • ell: KDU 02 n . SCHEMATIC Last Completed: 8/21/1968 IIileo.p Alaska,LL( PTD: 168-049 CASING DETAIL RKB:MSL=107' Size Type Wt/Grade/Conn ID Top Btm 20" Conductor N/A Surf 58' 20" 13-3/8' Surface 54.5/J-55/STC 12.615 Surf 1,317' 9-5/8" Intermediate 40/N-80/Seal Lock 8.835 Surf 6,027' 7" Liner 29/N-80/BTC 6.184 5,821' 10,522' TUBING DETAIL 3-1/2" Tubing 9.2/N-80/Butt Mod 2.992 Surf 2,085' 13-3/8" 1311. JEWELRY DETAIL .0: No Depth Item :7 11�35� ' 1 5,007' Cement Retainer All 2 5,385' Cement Retainer __ �, _ 1 i.{3l- 40124012.a4d 3 5,921' • Cement Retainer osi. V 1 4 7,861' Cement Retainer �wrt 5 9,325' Cement Retainer 2 6 9,500' Baker Packer TOC@ 5,750' ''*` `" ' x1 7 9,744' Junk Retainer 8 9,750' Cement Retainer _ 9-5/8" 602.7' 9 9,950' Cement Retainer 10 10,436' Junk Retainer 11 10,477' Cement Retainer . - 3 ACTIVE PERFORATION DETAIL Btm Sands Top(MD) Btm(MD) Top(ND) (TVD) FT Date Status Sterling All 4,310' 4,350' 3,804' 3,839' 40 TBD Proposed - Sterling B1 4,380' 4,420' 3,865' 3,900' 40 TBD Proposed • ISOLATED PERFORATION DETAIL 5,119' 5,120' 4,538' 4,539' 1' 5/17/2013 Squeezed Retainer@ 7,861' 5,128' 5,138' 4,546' 4,556' 10' 5/17/2013 Squeezed 4 Sterling Pool 6 5,170' 5,190' 4,586' 4,605' 20' 5/17/2013 Squeezed Collapsed 5,235' 5,265' 4,648' 4,676' 30' 5/17/2013 Squeezed all ,, Casing @ i UT/72-8 7,911' 7,951' 7,276' 7,280' 40 3/18/1996 Squeezed 7,931' 1 UT/73-1 7,973' 7,992' 7,338' 7,357' 19 3/18/1996 Squeezed t UT/75-8 8,220' 8,262' 7,584' 7,626' 42 11/29/1995 Squeezed Upper Ty/Bel 8,245' 8,255' 7,609' 7,618' 10' Nov-95 Squeezed 9,510' 9,522' 8,874' 8,886' 12' 8/13/1968 Isolated 9,558' 9,588' 8,922' 8,952' 30' 9,854' 9,874' 9,218' 9,238' 20' Tyonek 9,884' 9,910' 9,248' 9,274' 26' 8/4/1974 Squeezed 9,919' 9,920' 9,283' 9,284' 1' 10,006' 10,007' 9,370' 9,371' 1' 7/27/1974 10,028' 10,036' 9,392' 9,400' 8' 8/13/1968 Isolated 10,080' 10,092' 9,443' 9,455' 12' 8/13/1968 TOFTaa:ed @ 8,432'-10/15/2010 5-11 OPEN HOLE/CEMENT DETAIL 13-3/8" Cmt w/650 sks of class"G" 9-5/8" Cmt w/700 sks of class"G"through shoe&w/300 sks thru DV tool @1918' 7" Cmt w/1000 sks of class"G" TD=10,522' PBTD=10,477' Modified By:TWN 3/4/2016 • • • Kenai Gas Field KDU #2 04/05/2013 Ilrl.,rl+ *I;nt,.r.1.1.1: Kenai Gas Field Tubing hanger,CIW-DCB- KDU#2 FBB,11 X 3% EUE 8rd lift 13 3/8 X 9 5/8 X 3 1/2 and 3 1/2 EUE susp, w/3"type H BPV profile, 6 1/4" EN,W' non continuous control line Tree cap Otis,3 1/8 5M FE X 6 1/2 Otis Quick Union U+ Si Valve,swab,WKM-M, ,. 3 1/8 5M FE,HWO,T-24 i• Valve,Wing, ®®' VG-200,3 1/8 5M FE,w/ .. .+ Axelson MHA oper, DD trim Tee,stdd,3 1/8 5M X _ O 3 1/8 5M Valve, upper master, WKM-M, 3 1/8 5M FE, HWO, ='! - o T-24 CIO 115Or 1.. Valve, lower master, WKM-M, 3 1/8 SM FE, HWO, T-24 ® Adapter, CIW-FBB, 11 5M FE X fill '" 17T 3 1/8 5M, prepped for 6%" --- extended neck, 1/2npt control line port Tubing head,CIW-DCB, 1;/ am 13 5/8 3M X 11 5M,w/2- Valve,CIW-FC,2 1/16 5M FE, 2 1/16 5M SSO, X-bottom •) HWO, AA prep, 1 1/2 VR profile gm Ito/ 411 Ui-1•.. o ma ■ Casing head, /1111 Shaffer KD, • II, 135/83MX 13 3/8 SOW,w/2-2' ® 2"LP CIW ball valve LPO, Irl MIMI10 11.1. � I • • • II Kenai Gas Field KDU-02 03/04/2016 l .orp %►A*,tax: I KDU-02 Coil Tubing BOP 4 Lubricator to injection head l I 1.75" Tandem Stripper 1 I 1.IuIi11) Blind/Shea�=1 1/16 10 =i Blind/Shear .I,I■ mm .III, Blind/Shear Blind/Shear i.i.i ( ■ • 00 mion— = Slip =— — ® Slip ■I,'■ i - ■LI, Pipe • Pipe .I,'• Mud Cross I IIIMMI i_ �iiimm ; 4 1/16 10M X 4 1/16 10M ill _ Outlet w/ 2- 2 1/16 10M full ■� opening FMC valves MI I.1 - _ c _ : me !m1 _. IIIIII[ II i 0 _ Ell l_l �W illi i -s am let Manual Manual Manual Manual 2 1/16 10M 2 1/16 10M 2 1/16 10M 2 1/16 10M Crossover spool 4 1/16 10M X 3 1/8 5M • • ' 8] D U Ca g 'i C 1- m U U N 9 '] Q cT5z z o l I l % ') 9Z ° II (J) F 0 I- C U ./ ►•/ Z 1 ^ gin W N yi V �j O 3 ES �� = 25 Y C C • A:47, I1 U e ' ' I A N lig• Z • S 4 0040 0 U U 0 O d 1 iiiI 4 i IIII III III III — 111"IIII 0 IIIA11.11; del' 14 1111 1111 till is - - 1 N I II 1 0 In`�jn7�7' SI' io) 13 \\.___„,/ t � k b $ IIID .-, rn c rn D ,_ c 01111, n �m a a ht gl oo Z 11 $`9 O �tl 0 i k 3 i • 1 83 ..,---N Y ' J CD F 1- m En O i .] LL y .] l Lw Z F y t 7 g 3 O U O'- L.-, C-) Ail 001 N 9 U Z l' I 5555 N g y ass •A• � Z N z a) _ - cn o U v Z p a) a` (2 o i— I I�I I11:. IIII IIA -. -I VIII ® uII!II■N' ilio , d ill's All lul _ g c O H G a .- 1 1 c N ir V • A 0 II i O I s _ ! k i 8 ht L I Di c �rncO .CVZ Z 011 N g s 5 E i 0 0 Kenai Gas Field KDU #2 CBL of 9-5/8" ��,�.,,.,, v.,.ka.ILIA: 02/05/2016 i s it I I O • 1t t ' 7. I it { 1 iI 4) • -_ 4 " Pr' [ . kk 1 . . .1 A /./ . . t t : 0 , c 11 :., d 1 _.,.. ,, U , . . , 1 1 1;lq'/4 i •i ft , 4 i 1 c G . 1.1.=11.1111111.11111111.1 .1.1=1111.1111111.17.11...1=1611717 '� OF Tit hie\� I//j,7 8), THE STATE Alaska Oil and Gas ' Ti OfA T A 1 Conservation Commission 333 West Seventh Avenue " tet ^— I r Anchorage, Alaska 99501-3572 ��T„ GOVERNOR BILL WALKER 9 "4, Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 3(ANNE ` F 'E Anchorage,AK 99503 Re: Kenai Field, Beluga-Upper Tyonek and Sterling 6 Gas Pools,KDU 2 (21-8) Permit to Drill Number: 168-049 Sundry Number: 316-106 Dear Mr. Helgeson: 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, Cathy P. Foerster Chair DATED this J6 day of February, 2016. RBDMS FEB 1 6 2016 • • RECEIVED STATE OF ALASKA FEB 0 5 2016 ' ALASKA OIL AND GAS CONSERVATION COMMISSION Z-/'/,4/lam APPLICATION FOR SUNDRY APPROVALS �+,� , 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate 0- Other Stimulate ❑ Pull Tubing Q . Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well Q . Alter Casing ❑ Other: CT N2 Jetting E. 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development ❑✓ 168-049 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20121-00 - 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 510A Kenai Deep (Unit 2 21-8) Will planned perforations require a spacing exception? Yes ❑ No 0 9. Property Designation(Lease Number): 10. Field/Pool(s): - FEDA028142 Kenai Gas Field/Beluga-Upper Tyonek&Sterling 6 Gas - 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): 10,522' ' 9,885' • 5,007' 4,433' 1,287psi 5,007' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 58' 20" 58' 58' Surface 1,317' 13-3/8" 1,317' 1,291' 2,730psi 1,130psi Intermediate 6,027' 9-5/8" 6,027' 5,418' 5,750psi 3,090psi Production Liner 4,701' 7" 10,522' 9,898' 8,160psi 7,020psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.2#/N-80 2,085' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A; N/A N/A;N/A 12.Attachments: Proposal Summary ❑✓ Wellbore schematic n 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic ❑ Development Service ❑ 14. Estimated Date for 15.Well Status after proposed work: Commencing Operations: February 19,2016 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS E - 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. Contact Taylor Nasse-777-8354 Email tnasse( hilcorD.com Printed Name Chad Helgeson Title Operations Manager Signature (y// i� Phone 907-777-8405 Date Z/7// c COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3\(4 - \o (.e Plug Integrity ❑ BOP Test WI Mechanical Integrity Test ❑ Location Clearance ❑ Other: 4. 2 DO PS1 sup ' A►•.»%.,..tJ jP .. "it-sT St,AARC St/0..3 t:42-Nt R.ellArReb TO Pw..C, Pe-12.Fs Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No ❑` Subsequent Form Required: 1 O—401 RBDMS i.(- FEB 1 6 2016 p APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 2- / _// ;€1,e,..,4.___ -allit Submit Form and Form 10-403 Revised 11/2015 0 ,Ir , i a s valid for 12 months from the date of approval. � achments In Duplicate r Well Prognosis • Well: KDU-02 Hilcorp Alaska,LL Date:02/04/2016 Well Name: KDU-02 API Number: 50-133-20121-00 Current Status: Suspended Gas Well - Leg: N/A Estimated Start Date: 02/19/16 Rig: Moncla 401 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 168-049 First Call Engineer: Taylor Nasse (907) 777-8354 (0) (907)903-0341 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824(M) AFE Number: Current Surface Pressure: 0 psi Maximum Expected BHP: — 1,677 psi @ 3,900' TVD (Assumed 0.43 psi/ft gradient) Max. Potential Surface Pressure: — 1,287 psi ✓ (Assumed 0.10 psi/ft gas gradient) Brief Well Summary KDU-02 was drilled as a grassroots well to target gas sands in the Tyonek formations. Hilcorp Alaska previously attempted to re-enter the well to test additional deep Tyonek sands but was unsuccessful and temporarily suspended the well. The purpose of this work/sundry is to run a new 7" completion and perforate the Sterling B1 and All sands. Notes Regarding Wellbore Condition • Tubing and casing will be filled full of produced fluid. Safety Concerns • Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter, i.e. near flow-back tank(Coiled tubing work). • Consider tank placement based on wind direction and current weather forecast (venting nitrogen during this job) (Coiled tubing work) • Ensure all crews are aware of stop job authority(All crews) WO Rig Procedure: 1. MIRU Moncla #401 WO Rig. 2. Circulate well with 8.4 ppg 3% KCI inhibited fluid down tubing. Z 3. Set BPV. ND Tree. 2Soo PS% �� 4. NU 13-5/8" BOPE. Test to 250 psi Low/2,500 psi High, annular to 250 psi Low4.11h0O psi High (hold each valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance of BOP test. b. Test VBR rams on 7" test joint and 3-1/2" test joint. 5. Bleed any pressure off tubing. Pull BPV. 6. MU landing joint and pull 10k tension over string weight on tubing hanger. 7. POOH. Lay down 3-1/2" tubing hanger and tubing. 8. RU slickline. 9. RIH w/9-5/8"gauge ring (8.5"). Well Prognosis • Well: KDU-02 IJ; Date:02/04/2016 a. If gauge ring tags above 1,500', MU mill and casing scraper for 9-5/8" on 3-1/2" tubing and RIH to 1,600'. b. Circulate bottoms up x 2 with 8.4 ppg 3% KCI. c. SOOH. Lay down mill and scraper. 10. MU completion per the proposed schematic, consisting of 7" tubing, WLEG/collar, profile nipple, and hydraulic permanent packer. 11. RIH with 7" completion. Land tubing in hanger. 12. RU slickline. 13. RIH and set plug in X-nipple below packer. 14. Pressure the tubing to 2,500 PSI and hold for ten minutes to set packer. ✓ 15. Releasep ressure. 16. Test tubing to 2,500 psi for 30 min.✓ 17. Pull plug in x-nipple and RD slickline. 18. Close preventer and test packer/tubing annulus to 1,500 psi for ten minutes. ✓ 19. Release annulus pressure and open preventer. 20. Set BPV. ND BOPE. NU tree. Pull BPV. 21. Set TWC.Test tubing hanger and tree to 250/5,000 psi. Pull TWC. 22. RD Moncla #401 WO Rig. 23. Replace IA x OA pressure gauge if removed (9-5/8" x 13-3/8"). Coiled Tubing Procedure: 24. Submit 24 hr. witness notification to AOGCC via web base notification.,---- 25. otification.✓25. MIRU Coiled Tubing, PT BOPE to 250/4500 psi. ✓' 26. Isolate production flow line. Route well production to open top diffuser 400 bbl tank. 27. Pressure test N2 lines to 4,500 psi prior to starting job. 28. RIH whet nozzle BHA to 5,007' MD and tag PBTD. 29. PU 10ft and displace well fluids with Nitrogen. a. Estimated volume of displaced 6% KCI is 380 bbl. (Reverse N2 jet) 30. Leave well with+/- 150 psi nitrogen SITP. 31. POOH w/coil. LD jet nozzle BHA. 32. RD Coiled Tubing. E-Line Procedure 1. MIRU a-line and pressure control equipment. PT lubricator to 250 psi low/1,500 psi high. Note that the well is pressurized with nitrogen. a. If necessary, bleed nitrogen pressure down as requested by the RE to establish a drawdown on the formation. 2. Perforate the Sterling sands with 3-3/8" 6 SPF 60 deg phased perf guns. All intervals are planned for 12 SPF so each zone may be shot twice. Send the correlation pass to Operations Engineer, Reservoir Engineer, and Geologist for confirmation. Gross Proposed Perforated Intervals Sands Top (MD) Btm (MD) FT Sterling B1 ±4,380 ±4,420 ±40 Sterling All ±4,310 ±4,350 ±40 • • • 14Well Prognosis • Well: KDU-02 Hhlcoru Alaska,LL Date:02/04/2016 3. POOH. 4. Individually flow each zone through test separator and record water and gas rates. 5. If any of the Sterling sands are not commercial or wet,the zone will be permanently pluggedluback. 6. RD a line. 10-4o Sv.e-+Dcc y AC014.ut2r0 7. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic 3. Wellhead Diagram 4. Moncla 401 BOPE Schematic 5. CT BOPE Schematic 6. CT Schematic(forward and reverse jetting) 7. CBL of 9-5/8"casing showing cement above proposed perforations H . , Kenai Gas Field .13Well: KDU 02 Sc• H E IViATI C Last Completed: 8/21/1968 linear!)Alaska,LLC PTD: 168-049 CASING DETAIL RKB:MSL=107 Size Type Wt/Grade/Conn ID Top Btm I 20 Conductor N/A Surf 58' ` 13 3/8' Surface 54.5/J-55/STC 12.615 Surf 1,317' 9-5/8" Intermediate 40/N-80/Seal Lock 8.835 Surf 6,027' 7" Liner 29/N-80/BTC 6.184 5,821' 10,522' TUBING DETAIL 3-1/2" Tubing 9.2/N-80/Butt Mod 2.992 Surf 2,085' 13-3/8" JEWELRY DETAIL No Depth Item 1 5,007' Cement Retainer 2 5,385' Cement Retainer 3 5,921' Cement Retainer 1 4 7,861' Cement Retainer ieAyIr ` 5 9,325' Cement Retainer 6 9,500 Baker Packer TOC@ 5,750' 2 7 9,744' Junk Retainer V 8 9,750' Cement Retainer 9-5/8"A ;'.,.03:, 9 9,950' Cement Retainer k 10 10,436' Junk Retainer ,E , 11 10,477' Cement Retainer ACTIVE PERFORATION DETAIL Btm Sands Top(MD) Btm(MD) Top(TVD) (TVD) FT Date Status UT/72-8 7,911' 7,951' 7,276' 7,280' 40 3/18/1996 Squeeze UT/73-1 7,973' 7,992' 7,338' 7,357' 19 Squeeze UT/75-8 8,220' 8,262' 7,584' 7,626' 42 11/29/1995 Squeeze ISOLATED PERFORATION DETAIL Retainer@ 7,861' 5,119' 5,120' 4,538' 4,539' 1' ►_-_4 et Sterling Pool 6 5,128' 5,138' 4,546' 4,556' 10' Colla sed :" 5,170' 5,190' 4,586' 4,605' 20' Nov-95 Squeezed P ung@ ' 5,235' 5,265' 4,648' 4,676' 30' 7,931' Upper Ty/Bel 8,245' 8,255' 7,609' 7,618' 10' 9,510' 9,522' 8,874' 8,886' 12' 8/13/1968 Isolated 9,558' 9,588' 8,922' 8,952' 30' .. 9,854' 9,874' 9,218' 9,238' 20' 9,884' 9,910' 9,248' 9,274' 26' 8/4/1974 Squeezed Tyonek - 9,919' 9,920' 9,283' 9,284' 1' 10,006' 10,007' 9,370' 9,371' 1' 7/27/1974 10,028' 10,036' 9,392' 9,400' 8' 8/13/1968 Isolated 10,080' 10,092' 9,443' 9,455' 12' 8/13/1968 OPEN HOLE/CEMENT DETAIL 13-3/8" Cmt w/650 sks of class"G" TOFTagged @ 9-5/8" Cmt w/700 sks of class"G"through shoe&w/300 sks thru DV tool @1918' 8,432'-10/15/2010 7" Cmt w/1000 sks of class"G" 1 4 -45 0. w TD=10,522' PBTD=10,477' Created By:TDF 5/28/2013 • PROPOSED •• Kenai Gas Field ,Il Well: KDU 02 SCHEMATIC Last Completed: 8/21/1968 1sicor„Alaska,LLC PTD: 168-049 CASING DETAIL RKB:MSL=107 Size Type Wt/Grade/Conn ID Top Btm 20"20" Conductor Surf 58' 13 3/8' Surface 54.5/N1-/5A5/STC 12.615 Surf 1,317' 9-5/8" Intermediate 40/N-80/Seal Lock 8.835 Surf 6,027' 7" Liner 29/N-80/BTC 6.184 5,821' 10,522' TUBING DETAIL 7" Tubing I 26/L-80 6.276 Surf 1,530' 13-3/8" °171 JEWELRY DETAIL RPI No Depth Item 1 1,500' Hyd.Perm.Packer 2 1,515' RN Nipple 3 1,530' WLEG/Collar 4 5,007' Cement Retainer 5 5,385' Cement Retainer 6 5,921' Cement Retainer TOC@ 5,750' - - 5 7 7,861' Cement Retainer 8 9,325' Cement Retainer 9-5/8" 9 9,500' Baker Packer 10 9,744' Junk Retainer 11 9,750' Cement Retainer 6 12 9,950' Cement Retainer 13 10,436' Junk Retainer 14 10,477' Cement Retainer ACTIVE PERFORATION DETAIL Retainer@ 7,861' , Sands Top(MD) Btm(MD) Top(TVD) (TVD) FT Date Status 7 Sterling All 4,310' 4,350' 3,804' 3,839' 40 TBD Proposed '4'4! Sterling B1 4,380' 4,420' 3,865' 3,900' 40 TBD Proposed Collapsed .,.. Casing ..„ ' `� ISOLATED PERFORATION DETAIL 7,931' 5,119' 5,120' 4,538' 4,539' 1' 5/17/2013 Squeezed 5,128' 5,138' 4,546' 4,556' 10' 5/17/2013 Squeezed Sterling Pool 6 5,170' 5,190' 4,586' 4,605' 20' 5/17/2013 Squeezed A 5,235' 5,265' 4,648' 4,676' 30' 5/17/2013 Squeezed UT/72-8 7,911' 7,951' 7,276' 7,280' 40 3/18/1996 Squeezed UT/73-1 7,973' 7,992' 7,338' 7,357' 19 3/18/1996 Squeezed UT/75-8 8,220' 8,262' 7,584' 7,626' 42 11/29/1995 Squeezed Upper Ty/Bel 8,245' 8,255' 7,609' 7,618' 10' Nov-95 Squeezed 9,510' 9,522' 8,874' 8,886' 12' 8/13/1968 Isolated 9,558' 9,588' 8,922' 8,952' 30' 9,854' 9,874' 9,218' 9,238' 20' Tyonek 9,884' 9,910' 9,248' 9,274' 26' 8/4/1974 Squeezed TOFTagged @ y 9,919' 9,920' 9,283' 9,284' 1' 8,432'-10/15/2010 in 10,006' 10,007' 9,370' 9,371' 1' 7/27/1974 F18-14', 10,028' 10,036' 9,392' 9,400' 8' 8/13/1968 Isolated 10,080' 10,092' 9,443' 9,455' 12' 8/13/1968 Lam. + OPEN HOLE/CEMENT DETAIL `7'+ 13-3/8" Cmt w/650 sks of class"G" , p -t=, 9-5/8" Cmt w/700 sks of class"G"through shoe&w/300 sks thru DV tool @1918' 7" Cmt w/1000 sks of class"G" TD=10,522' PBTD=10,477' Modified By:TWN 2/4/2016 0 • Kenai Gas Field KDU#2 Proposed 02/02/2016 !blew r ‘I:,.k.,,I.I.I. Kenai Gas Field Tubing hanger,CIW-DCB- KDU#2 FBB,11 X 7"LH acme lift 133/8 X95/8 X7 and 7"BTC susp, w/6"type H BPV profile, 9"EN Tree cap,Otis,7 1/16 5M FE X 9 Y.Otis Quick Union 1111 .11 lel IMINNINIMMI Valve,swab, , _ 1. CIW-FC,7 1/16 5M FE xr 6 3/8 bore,HWO,EE trim ®^ �0- ,,,�R` �b�o< �a\�e'N.4,*--' F' �0.�,' �� ©OAhlyi p1�6h �a\�16�'�E``\� Valve,Wing,WKM M, A1� 2 1/16 5M FE,HWO AA /''F-1J .. 0 jilt CI 1- = • ' • ®0 %I _ ;'/ _ N _ Valve,upper master, - ' /X® CIW-FC,7 1/16 5M FE x 6 3/8 bore,HWO,EE trim Valve,lower master, 0 CIW-FC,7 1/16 5M FE x _.,1,) I4 6 3/8 bore,HWO,EE trim 44 `t ® O Adapter,CIW-FBB,11 5M Stdd „........,.e.. X 7 1/16 5M,prepped for 9” Li extended neck Valve,CIW-FL,2 1/16 5M FE, Tubinghead,CIW-DCB, � HWO,AA 13 5/8 3M X 11 5M,w/2- - /00 1 2 1/16 SM 550,X-bottom — (m�;0,l o prep,1'/:VR profile v�O rel ■ Casing head, -• - _j Shaffer KD, @ ��!! 135/83MX 13 3/8 SOW,w/2-2" I `; ■111.1,1 2"LP CIW ball valve LPO, I 1 13 3/8" 9 5/8" 7" • ll • • Kenai Gas Field Moncla 401 BOPE 02/04/2016 Hilrnrp tlarkn. CI)I.i.S. ifl iItttirtj 4.54' \IV 111111/ P[ Hyd ri l 4 GK 13 5/8-5000 r III Ili Ill lli IV III I III III tr— 2 7/8-5 variables cn64.67' H CU Blinds Ili I I iii rii III 2 1/16 5M Choke and Kill 111111111111.1111111 tIl 2.00' _ 1 rE+IL t iIiO valves retail,111 ril Ill IF LU IV 1 Crossover spool 13 5/8 5M FE X 13 5/8 3M FE • Kenai Gas Field KDU-02 11,1-1. ‘I `k 02/04/2016 1 Ili KDU-02 Coil Tubing BOP 3 Lubricator to injection head 0 (_ I I 1.75" Tandem Stripper J= Blind/Shear 1 1/16 10M Blind/Shear :3 —_ G ——f c= Blind/Shear Blind/Shear _ _ : 1 • _ ,"® ir : Slip Slip liii' ■ 11 sem— — ' = Pipe Pipe : 3 Mud Cross _- _ C / — 4 1/16 10M X 4 1/16 10M Outlet w/ 2- 2 1/16 10M full opening FMC valves 111111 CO I 0 ' n a hi Manual Manual Manual Manual 2 1/16 10M 2 1/16 10M 11:1/ 2 1/16 10M 2 1/16 10M Crossover spool 11. Ifi1' 4 1/16 10M X 7 1/16 5M • • < z 83 (1) ] D U ! 1J Y Y 1 U ] U N I .J Z Q O]O 1 .l ~ y W Z 1 1 Q W I N p D Al 111141 , Z t :111 N A A 0 ; - aY • N Z �4 ►•t O Li 0 3 U O n O 1- i i I'I 11 III I� — IMOII"II t, III■Il.I! IIu • i, N it IIu IIII IIII IIII • w .. I w CI . I Oi o a -7-, v� s A Z c O I- o.n 0 r I 1; V • A 4111111 7 ._(..i_D i . I • ., m s : : a �I a c it rn n ki c 0 0 N n U N 0 0 11 LL 0 1 L N 3 • • < ig3 1 : .3 U F ¢ '3 j '-1-' 1 , ] 1— 1 z m o 1 .] O a z Y ' 1- 1! 1 l{1. A 1 a i c 1 (1„) L: 10,4 (NI z a) cn n� 47, o W U J Z L O a` cL 0 e la I-l�IiII ® 111!11■1; '101'. . MI 1111 1111 I • H o, o Y C O 5, H O. O H I c • • O 11 A V •A Olilli O--- i O 1 It N • , 11 c 11 ~ O g- -0 2 U N O Z O11 O g L G • S Kenai Gas Field . 11 KDU#2 CBL of 9-5/8" r.r n i...1v...►... 02/05/2016 1 1i* 1 A t 1 f L —t .. .. --a, t 1. ` j j A A Q j I is 4 I --- --`---- —-----_' " 1 R I G 1 (t 7 I, 1 ' STATE OF ALASKA _ ALlikA OIL AND GAS CONSERVATION CO SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Suspended Well Inspection E 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC lorato❑ment Develo E Exploratory p ry ❑ 168-049 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic riii Service ❑ 6.API Number: Anchorage,AK 99503 - 50-133-20121-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: • FEDA028142 . Kenai Deep Unit 2(21-8) 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A • Kenai Field/Beluga/Upper Tyonek&Sterling 6 Gas 11.Present Well Condition Summary: 5,007;5,385'5,921; Total Depth measured t 10,522 feet Plugs measured 7,861;9,485 feet ,"cEIVE vertical 9,885 feet Junk measured N/A feet M Effective Depth measured 5,007 feet Packer measured 9,500 feetsEP 1 1 2015 true vertical 4,433 feet true vertical 8,864 feet f[/"'"��)� [}�- V�.r�I C V Casing Length Size MD TVD Burst Collapse Structural Conductor 58' 20" 58' 58' Surface 1,317' 13-3/8" 1,317' 12,901' 2,730 psi 1,130 psi Intermediate 6,027' 9-5/8" 6,026' 5,418' 5,750 psi 3,090 psi Production Liner 4,701' 7" 10,522' 9,898' 8,160 psi 7,020 psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic n (size,grade,measured and true vertical depth) 205 Tubing P ) 3-1/2" 9.2#/N-80 2,085'MD 2,085'TVD Packers and SSSV(type,measured and true vertical depth) N/A; N/A N/A;N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑ Exploratory❑ Development Ei 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. 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: N/A Contact Taylor Nasse Email tnasse@hilcorp.com Printed Name�J Taylor Nasse Title Operations Engineer Signature Phone 907-777-8354 Date ?///I S Form 10-404 Revised 5/2015 )4. 7./7-/5- RBDMS SEP 1 5 1015 Submit Original Only i /7(7//f • • Suspended Well Inspection Data Well: Kenai Deep Unit 2(21-8) Surface Location: 337' FNL, 4,274' FWL, Sec. 7, T4N, R11W, S.M. Permit to Drill: 168-049 API: 50-133-20121-00-00 AOGCC Inspection Date: 08-17-15 AOGCC Inspector: Johnnie Hill Operator Rep: Mike Chivers Size Pressure (psi) Tubing 3-1/2" 0 Casing IA 9-5/8" 0 Casing OA 13-3/8" 0 *Note: Wellhead pressures to be recorded monthly at minimum. Other Notes: • Condition of Wellhead: Good • Condition of Surrounding Surface Location: Good • Follow Up Actions Needed: None Attachments: • Current Well Schematic • Pictures (2) • Plat- 1/4 mile radius of wellbore (KEN July 2015) .. 14 • Kenai Gas Field • Well: KDU 02 SCHEMATIC Last Completed: 8/21/1968 Hilcorp Alaska,LLC PTD: 168-049 CASING DETAIL RKB:MSL=107 Size Type Wt/Grade/Conn ID Top Btm 20" I I20" Conductor N/A Surf 58' 13 3/8' Surface 54.5/1-55/STC 12.615 Surf 1,317' 9-5/8" Intermediate 40/N-80/Seal Lock 8.835 Surf 6,027' 7" Liner 29/N-80/BTC 6.184 5,821' 10,522' TUBING DETAIL 3-1/2" Tubing 9.2/N-80/Butt Mod 2.992 Surf 2,085' 13-3/8" JEWELRY DETAIL - No Depth Item 1 5,007' Cement Retainer 2 5,385' Cement Retainer 3 5,921' Cement Retainer 4 7,861' Cement Retainer 1 o t 5 9,325' Cement Retainer 6 9,500' Baker Packer TOC @5,750' - 2 7 9,744' Junk Retainer ;al''" A.:.J8 9,750' Cement Retainer 9-5/8"• ys"{ • 9 9,950' Cement Retainer •,-$.., 10 10,436' Junk Retainer 11 10,477' Cement Retainer ,. , 3 ACTIVE PERFORATION DETAIL IRM Sands Top(MD) Btm(MD) Top(ND) (TVD) FT Date Status UT/72-8 7,911' 7,951' 7,276' 7,280' 40 Squeeze UT/73-1 7,973' 7,992' 7,338' 7,357' 19 3/18/1996 Squeeze UT/75-8 8,220' 8,262' 7,584' 7,626' 42 11/29/1995 Squeeze ISOLATED PERFORATION DETAIL Retainer@ 7,861' 5,119' 5,120' 4,538' 4,539' 1' 4 5,128' 5,138' 4,546' 4,556' 10' Colla sed '`+ Sterling Pool 6 5,170' 5,190' 4,586' 4,605' 20' Nov-95 Squeezed p ,,. °" Casing @ 5,235' 5,265' 4,648' 4,676' 30' 7,931' C Upper Ty/Bel 8,245' 8,255' 7,609' 7,618' 10' 9,510' 9,522' _ 8,874' 8,886' 12' 9,558' 9,588' 8,922' 8,952' 30' 8/13/1968 Isolated E31) 9,854' 9,874' 9,218' 9,238' 20' Tyonek 9,884' 9,910' 9,248' 9,274' 26' 8/4/1974 Squeezed 9,919' 9,920' 9,283' _ 9,284' 1' 10,006' 10,007' _ 9,370' 9,371' 1' 7/27/1974 10,028' 10,036' _ 9,392' 9,400' 8' 8/13/1968 Isolated 10,080' 10,092' 9,443' 9,455' 12' 8/13/1968 OPEN HOLE/CEMENT DETAIL 13-3/8" Cmt w/650 sks of class"G" TOF Tagged @ 9-5/8" Cmt w/700 sks of class"G"through shoe&w/300 sks thru DV tool @1918' 8,432'-10/15/2010 7" Cmt w/1000 sks of class"G" .45 A .•,i TD=10,522' PBTD=10,477' Created By:TDF 5/28/2013 • • • NVliq , s 'm[ 11:1 'Nit' i1- °-as '17/1.3N `tiON :NOuv001 30Vd8nS . ..._.- -----. 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','';'; , 'II .,'. ..,:.,i , ,- ,..-,e1.,.. .,•• ' ,,.., • 0 • KDU 03(KU 21-5) KBU 42-06Y KBU 12-05 KTU 13-05 KBU 23-05 KU 24-05 KU 24-05RD • KU 14-04 KBU 11-08X KDU 02(KU 2 8) \ KBU 11-08Y e U 11- U4 -07 KBU 11-08Z KBU 32-08 Hilcorp Alaska I Kenai Field Suspended Wells Quarter Mile Radius Map KDU2 �\ KBU 13-08 0 1D00 z000 KU 11-17 FEET POSTED WELL DATA KBU 14-08 Well Label ;UH.1 (KU 41-18)_- • WELL SYMBOLS Gas Well Location Well O Location Only Plugged and Abandoned Shut-in Gas Well KBU 11-17X `1 Unmown Status September 2,2015 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/17/15 Inspector: Johnnie Hill Operator: Hilcorp Well Name: Kenai Deep Unit 2(21-8) - Oper.Rep: Mike Chivers PTD No.: 1680490 Oper.Phone: 283-1345 Location Verified? Yes Oper.Email: If Verified,How? LAT/LONG Onshore/Offshore: Onshore Suspension Date: 05/09/13 Date AOGCC Notified: 08/14/15 - Sundry No.: 313-220 - Type of Inspection: Subsequent Wellbore Diagram Avail.? No Well Pressures(psi): Tubing 0 Photos Taken? Yes IA 0 OA 0 • Condition of Wellhead: good Condition of Surrounding Surface Location: good gravel Follow Up Actions Needed: none Comments: well was verified by pad well location map Attachments: Photos(2) REVIEWED BY: Insp.Supry Comm PLB 06/2014 SCANNED SEP 0-7 2016 2015-0817_Suspend_KDU-2(21-8)jh.xlsx 111)i., i, t • Suspended Well Inspection—KDU 2(21-8) PTD 1680490 Photos by AOGCC Inspector J. Hill 8/17/2015 '1:;;...."''.IIP,iii:::4 `` 4r ..«. — c v . ,,=S. Ca Hilcorp Alaskst,° - KENAI DEEP UNIT 2(21-8) (KW 2214 ; . - e., API#50-133-20121-00-00 PTD#168-049 LEASE#FEDA028142 •SURFACE LOCATION • NEI/4,NE1/4,SEC 7,T4N,R11W,SII,AK Ss I r, .'„ .y r _e e,-- ?` WN d b' k kr 9 3 °yam ASt'Y k '.., - 2015-0817_Suspend_KDU-2(21-8) photos jh.docx Page 1 of 1 , STATE OF ALASKA A E C ',. e .;, „ ALA. OIL AND GAS CONSERVATION COMMWION REPORT OF SUNDRY WELL OPERATIONS ? 3 0 2013 1. Operations Abandon U Repair Well ❑ Plug Perforations ❑ Perforate Li Other ❑ ~3 Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac 0 Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Suspend Well 0 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC . Development isl , Exploratory ❑ 168 -049 1 3 Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, Alaska 99503. • 50-133-20121r 00-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028142 Kenai Deep Unit 2(21 -8) • 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): N/A Kenai Field / Sterling 6 Gas • 11. Present Well Condition Summary: 5,007, 5,385, 5,921', 7,861' & Total Depth measured 10,522 feet Plugs measured 9,485' feet true vertical 9,885 feet Junk measured N/A feet Effective Depth measured 5,007 feet Packer measured 9,500 feet true vertical 4,433 feet true vertical 8,864' feet rasing Length Size MD TVD Burst Collapse Structural Conductor 58' 20" 58' 58' Surface 1,317' 13 -3/8" 1,317' 1,291' 2,730psi • Intermediate 6,027' 9 -5/8" 6,026' 5,418' Production Liner 4,701' 7" 10,522' 9,898' '; erforation depth Measured depth See Attached Schematic 0 2013 SCANNED JUL True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 3 -1/2" 9.2# / N -80 2,085' 1,955' Packers and SSSV (type, measured and true vertical depth) N/A N/A N/A N/A 12. Stimulation or cement squeeze summary: Cement Intervals treated (measured): Set #1: 7,911' - 7,951'; 7,973' - 7,992'; 8,220' - 8,262'. Set #2 Re- squeeze: 5,119' - 5,120';' 5,128' - 5,138'; 5,170' - 5,190'; 5,235' - 5,265' Treatment descriptions including volumes used and final pressure: Set #1: 30bbls of Class G 15.8ppg cement displaced w/ 41.2bbls brine. Set #2 22.55bbls of Class (3 15.85ppg cement displaced w/ 24.5bbls of brine. 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 I 600 0 0 247 Subsequent to operation: 0 0 0 0 0 4 .4. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development i0 • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP E SPLUG ❑ w ' 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: , : 313 -220 Contact Jeremy Mardambek Email jmardambek(c�hilcorp.com Printed Name Jeremy Mardambek Title Reservoir Engineer [. Signature Phone 907 - 777 -8388 Date 5/28/2013 ir RBDMS MAY 31 201 Form 10 -404 Revised 10/2012 e d {/3 ubmit Original Only .411V ? /ice 11 • • Kenai Gas Field Well: KDU 02 SCHEMATIC Last Completed: 8/21/1968 Hilcora Alaska, LLC PTD: 168 -049 CASING DETAIL RKB: MSL =107' Size Type Wt/ Grade/ Conn ID Top Btm 20" L 20" Conductor N/A Surf 58' -3/8' Surface 54.5 / 1-55 / STC 12.615 Surf 1,317' 9 -5/8" Intermediate 40 / N -80 / Seal Lock 8.835 Surf 6,027' 7" Liner 29 / N -80 / BTC 6.184 5,821' 10,522' TUBING DETAIL 1 3 -1/2" 1 Tubing 9.2 / N -80 / Butt Mod I 2.992 Surf 2,085' 13 -3/8" JEWELRY DETAIL No Depth Item 1 5,007' Cement Retainer 2 5,385' Cement Retainer 3 5,921' Cement Retainer 4V J 1 4 7,861' Cement Retainer c 5 9,325' Cement Retainer +r.x 6 9,500' Baker Packer TOC@ 5,750' 2' 7 9,744' Junk Retainer 8 9,750' Cement Retainer 9-5/8" s Li 9 9,950' Cement Retainer ,Al 10 10,436' Junk Retainer v . "? 11 10,477' Cement Retainer 'C 3 ACTIVE PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) ( Np ) FT Date Status UT / 72 -8 7,911' 7,951' 7,276' 7,280' 40 Squeeze UT /73 -1 7,973' 7,992' 7,338' 7,357' 19 3/18/1996 Squeeze UT/75 -8 8,220' 8,262' 7,584' 7,626' 42 11/29/1995 Squeeze ISOLATED PERFORATION DETAIL Retainer@ 7,861' ! 5,119' 5,120' 4,538' 4,539' 1' I 4 5,128' 5,138' 4,546' 4,556' 10' Sterling Pool 6 Collapsed 5,170' 5,190' 4,586' 4,605' 20' Nov -95 Squeezed Casing@ 5,235' 5,265' 4,648' 4,676' 30' 7,931' Upper Ty /Bel 8,245' 8,255' 7,609' 7,618' 10' ■ rf 9,510' 9,522' 8,874' 8,886' 12' 8/13/1968 Isolated 9,558' 9,588' 8,922' 8,952' 30' 9,854' 9,874' 9,218' 9,238' 20' Tyonek 9,884' 9,910' 9,248' 9,274' 26' 8/4/1974 Squeezed 9,919' 9,920' 9,283' 9,284' 1' 10,006' 10,007' 9,370' 9,371' 1' 7/27/1974 10,028' 10,036' 9,392' 9,400' 8' 8/13/1968 Isolated 10,080' 10,092' 9,443' 9,455' 12' 8/13/1968 OPEN HOLE / CEMENT DETAIL 13 -3/8" Cmt w/ 650 sks of class "G" TOF Tagged @ 9 -5/8" Cmt w/ 700 sks of class "G" through shoe& w/ 300 sks thru DV tool @1918' 8,432' - 10/15/2010 _ 7" Cmt w/ 1000 sks of class "G" 1•Mit. LIE TD =10,522' PBTD = 10,477' Created By: TIN 5/28/2013 • • • Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date KDU -02 50- 133 - 20541 -00 -00 204 -107 4/18/13 5/9/13 4/17/2013 - Wednesday ` ' �...� ° �'' , No operations to report. 4/18 /2013 - Thursday i Put derrick on rig. RU tanks, Schlumberger Coil unit. NU Coil BOP's. Moved rig and equitment to location. Spot tanks. RU Schlumberger Coil unit. NU BOP's. Stab coil in injector. 4/19/2013 - Friday Put derrick on carrier. WO schlumberger coil tbg. Test BOPE to 250psi Low / 4,000psi High, Jim Regg w/ AOGCC wiaved witness of test. Kill well. Pump 180 bbls 6% KCL water. Open well. RIH and stab into packer at 300'. POOH. Cut packer off coil. Install roll -on coil connector. Pull V string OOH. RD for the night. 4 / 20 / 26 *_ - , - at daY, Waited on schlumberger C/T to rig down. RU pollard WL. Set plug in tbg at 1,100'. RD pollard WL. 4/21/2013 u MIRU. Bled pressure off of tbg. Loaded tbg w/ FIW. Set back pressure valve. ND flowline and tree. NU ROPE. 224.6,1— "=„-411 " ' r Performed BOPE test for AOGCC. Tested ok. Removed back pressure valve from tbg. RU pollard SLU. Pulled prong, plug body, and collar stop out of tbg. KW. RD SLU. Waited on pollard ELU and cutter. RU pollard ELU. . 3/2013 Tuesday Made radial cut at 7,642' above anchor pkr and sliding sleeve. RD pollard. POOH w/ 3.5" tbg and cap string. Well came in three times while Id 3.5" tbg. KW. Well did not come in, it was just out of balance w/ trapped gass. • • • Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date KDU -02 50- 133 - 20541 -00 -00 204 -107 4/18/13 5/9/13 w C.7,747 ; *r"WrAW4W: rr 't3PWMWT: 4/ - W . nesday '14 % r FOOH Id 3.5" tbg and cut piece. Attempted to stab tbg hanger to do state test on 2 -7/8" jt. Would not go into hanger . Tried several times w/ no success. Found one other tbg hanger. Tried that tbg hanger. Did not go into hanger. POOH. RIH w/ 20 jts 3.5" tbg and rtts pkr and set it at 62'. ND BOPE at hanger. 4/25/2013 - Thursday Realign BOPE. Put in hanger plug and 2 -7/8" test jt. Ran BOPE test for 2 -7/8 ". test went ok. nd test jt. released pkr . pooh Id pkr and 3 .5 tbg. wih w/ os , dc,ojs,bjs, pu 2 7/8" work string. 4/26/2013 - Friday - - Tagged hard at 4,413'. PUH. WIH and went by bad spot at 4,413'. POOH to look at lip guide on os. Lip guide was flared. Changed lip guide. WIH. Tagged spot at 4,413'. Rotated mill thru. CIH. Latched fish at 7,642' tm. Released anchor pkr. POOH. Recovered rest of fish. WL re -entry guide, 2 -x nipple,baker k pkr, sliding sleeve,pups,and cut piece of 3 .5" tbg. WIH w/ 8 -5/8" round nose mill. 4/27/2013 - Saturday FIH w /mill. Milled thru bad csg from 4,380' to 4,417'. Reamed several times freely. CO. POOH. WIH w/ 5 -3/4" burning shoe, 1 jts of wp, bjs,ojs, and ws. Starting burning over baker sab pkr. 4/28/2013 - Sunday Burn over pkr and pushed down hole to 7,936' and stopped. Jarred down on pkr. Unable to go down hole. SOOH dragging. POOH. Did not have fish. WIH w/ spear and same BHA. Spear fish and POOH. 4/29/2013 - Monday POOH w/ spear assembly to surface. Retrieved fish (tubing packer and tailpipe). WO AOGCC to waive witness of BOP test. Witnessed wavied by Jim Regg @ 10:00 4/29/13. WO Cameron to set test plug for BOP test. Attempt to set test plug for BOP test. Test plug would not pass through mud cross to tubing hanger. Wait on Halliburton to set RTTS. RIH w/ 47 stands of 2 -7/8" pipe and RTTS. MU test joint and set RTTS. Test BOPE as follows: annular 250psi low /2500psi high; 2 7/8 x 5 VBR, blind rams, NCR's, choke manifold, floor valves 250psi low /3000psi high - good test. Choke manifold valve #2 wouldn't seal, replace and tested good. AOGCC witness wavied by Jim Regg @ 10:00 4/29/13. Release RTTS and POOH w/ 47 stands of 2 7/8" pipe. MU mil! and scraper assembly and RIH on 2 -7/8" pipe. 4/30/2013 - Tuesday RIH w/ 6" tapered mill and scraper assembly in prep for running packers on injectivity test. Tag @ 7,933' RKB (top perfs) and unable to pass. Swivel up and attempt to mill through tight spot, making it to 7,936' with difficulty. Appears scraper is hanging up in perfs. POOH to PU tapered string mill (w /o scraper). POOH w/ tapered mill and scraper assembly. RIH w/ 6" tapered string mill and 6" blade mill on 2 -7/8" pipe. Tag @ 7,928'. Mill through tight spot and drop 15' to next tight spot, continue milling. Currently @ 7,952' (bottom of perfs) and losing ^'12 bbl /hr fluid since started milling. • • Hilcorp Alaska LLC Weekly Operations Summary Well Name IAPI Number Well Permit Number Start Date End Date KDU -02 50- 133 - 20541 -00 -00 204 -107 4/18/13 5/9/13 5/1/2013 - Wednesday M. :ll Continue milling on tight spot in casing. Made it to 7,952' (bottom of top set of perfs), POOH and check mill. POOH w/ 6" blade mill and tapered watermelon mill assembly. Blade mill showing wear indicating collapsed casing, worn ^'1" on outside edge. Tapered mill had no wear. Wait on smaller tapered mill from Knight. RIH w/ 1.75" x 4.75" tapered mill and 4.5" x 6" tapered watermelon mill on 2 -7/8" pipe. Begin milling & tag @ 7,952'. Made some progress then lost returns, pickup and unable to get returns. Attempt to circulate conventionally and found string plugged off. Troubleshoot. POOH to find where string is plugged. OOH. Everything below 2nd drill collar is packed off with sand. 5/2/2013 - Thursday Break and LD BHA (full of sand). WO new BHA. RIH w/ 2 - 7/8" x 6' mule shoe and 4 -3/4" x 6" watermelon mill on 2 -7/8" pipe. Break circulation @ 7,850' and circulate bottoms up- little sand returns. Wash to 7,900' and tag fill. Wash fill to damaged casing, putting mule shoe @ 7,962' MD RKB (mill tagging @ 7,955'). Begin putting WOB and lost returns, PU and regain returns. Circulate bottoms up- large sized coal and sandstone, cement, and metal filings to surface. Wait on more production fluid. Break circulation and tag same. Begin milling and losing returns with increased WOB. Repeat several times and experiencing heavy fluid losses. Same large returns to surface. Little /no progress milling. Wait on more production fluid. POOH above perfs and circulate bottoms up until clean. POOH w/ mule shoe and mill assembly. 5/3/2013 - Friday WO Pollard slickline. RU Pollard slickline. RIH w/ 1.75" RS, 10' stem, KJ, OJ, LSSJ, and 4.25" GR to 7,929' MD WLM and sat down. WT and fell to 7,946'. WT and would not pass. POOH- no marks. Fill hole (30 bbls) / WO smaller tools. RIH w/ same tool string and 3.83" GR. Tag @ 7,929', WT and fell to 7,946'. WT and would not pass. POOH- small metal marks. Fill hole (42 bbls). RIH w/ same tool string and 4.50" LIB. Sat down @ liner top (5,821') WT and would not pass. POOH. Fill hole (56 bbls). RIH w/ same tool string and 2.25" DD bailer. Tag @ 7,949' and WT to 7,951'. POOH- about 1 quart of mud /sand /coal. RIH w/ same tool string, 3.80" centralizer, and 2.25" DD bailer. Tag @ 7,951' WT and no progress. POOH- about 1 quart of mud /sand /coal. RIH w/ same tool string. 3.80" centralizer, and 3.50" LIB. Tag @ 7,931', spang down 2x and wouldn't fall. POOH- small gouge on one side. Decision to P &A well. RD Pollard. Remove plug in CIBP to convert to cement retainer per engineer. RIH w/ Halliburton EZ Drill cement retainer on 2 -7/8" pipe to 7,861' MD RKB. RU Baker cement unit. Fill hole (20 bbls) and break circulation. Set Halliburton EZ -Drill cement retainer @ 7,861' MD RKB. Isolate /cement squeeze Tyonek perfs 7,911 7,951', 7,973'- 7,992', 8,220' - 8,262' as follows: 3.5bbls below retainer and 0.5 bbls spotted on top. 19.5 sx Glass G 15.8ppg, displaced w/ 41.2bbls brine. RD Baker cementers, LD single, reverse circulate 1.5x string volume. Hole took 30 bbls to fill. POOH to continue P &A. i�IU�i h s'S 5/4/2013 - Sad '� ° �'� > _.. P ' .. _ POOH w/ retainer setting tool on 2 -7/8" pipe and LD 63 joints. Redress setting tool and MU 7" Halliburton EZ Drill CIBP. RIH w/ CIBP to 5,921' MD RKB. Fill hole (28 bbls) and break circulation. Set CIBP @ 5,921'. WO Baker Hughes cementers. RU Baker Hughes. Spot balanced cement plug on top of CIBP and above liner top as follows: 50 sacks class G (10 bbls) displaced w/ 27 bbls brine. POOH w/ 6 joints to 5,710', and reverse circulate work string clean 1.5 times. POOH w/ CIBP setting tool on 2 -7/8" pipe. WOC 24 hours. • . • z � , M U Halliburton 9 5/8" cement retainer. RIH w/ retain on 2 -7/8" pipe (85 stands) WOC. RIH 15 jts and tag cement top @ 5,750' MD RKB. LD 13 jts. Fill hole and break circulation. Set Halliburton 9 -5/8" cement retainer @ 5,385'. PT 9 -5/8" casing below retainer at 5,385' to 1,500psi for 10 min. Good test. WO Baker Hughes cementers. RU Baker Hughes. Unsting from cement retainer, spot balanced cement plug across previously squeezed Pool 6 perfs (5,119' - 5,120', 5,128' - 5,138', 5,170'- 5,190', 5,235' - 5,265') as follows: 26 bbls (130 sacks) class 'G' cement (15.5 ppg) displaced with 24.7 bbls brine. RD Baker Hughes. LD 12 joints, reverse circulate pipe 1.5x volume. POOH w/ cement retainer setting tool. 5/6/2013 - Monday POOH w/ cement retainer setting tool. WOC. PT 9 -5/8" casing above cement plug. Pressured up to 2,500psi and bled off quickly. Attempt to pressure up again and would not pressure up. Failed test. Prepare to test BOPE. RIH w/ 40 stands of 2- 7/8" pipe to hang off RTTS for test plug. 5/7 /2013 - Tuesday RIH w/ 40 stands 2 -7/8" pipe to hang below RTTS for BOP test. MU RTTS and test joint. Set RTTS. Jim Regg waived AOGCC witness 09:30 5/7/13. Test BOPE as follows: choke manifold, IBOP, TIW, inside kill valves, NCR's, and VBR's to 250psi low / 3,000psi high. Annular to 250psi low / 2,500psi high. Good test. POOH and LD RTTS. POOH 40 stands. MU RTTS and RIH t/ 5,004' MD RKB. Set RTTS and PT below, RTTS leaking. Release RTTS and reset at 5,007'. PT below, failed. PT above, held 2,500 psi. Establish injection rate below, 3bpm @ 1,600 psi, 2.25bpm @ 1250 psi, lbpm @ 550psi. Release RTTS and POOH. MU 9 -5/8" Halliburton EZ Drill cement retainer and RIH on 2 -7/8" pipe. ; Set cement retainer at 5,007' MD RKB. RU Baker Hughes cementers. Re- squeeze Pool 6 perfs (5,119' - 5,120', 5,128' - 5,138', 5,170'- 5,190', 5,235' - 5,265') below retainer as follows: 22.5 bbls class 'G' cement (130 sacks) @ 15.8ppg displaced with 24.5 bbls of brine. Held 400psi on squeeze, unsting from retainer and left 1 bbl cement on retainer. POOH and LD 3 joints. Reverse circulate tubing volume 2x. h 1 • Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date KDU -02 50- 133 - 20541 -00 -00 204 -107 4/18/13 5/9/13 5/8/2013 „,W • ' , ' POOH and LD 2 -7/8” pipe. LD RTTS. PT 9 -5/8" casing to 2,500psi for 30 minutes. Good test. ND BOP, troubleshoot mudcross /tubing hanger issue. RU to run 3 -1/2" kill string. RIH w/65 jts of 3 -1/2" 8rd. EOT @ 2,085' NU tubing hanger & production tree. Start RD WO unit. 5/9/2013 - Thursday , RDMO WOR and all equipment. 5/10/2013 - Friday No operations to report. 5/11/2013 - Saturday No operations to report. 5/12/2013 - Sunday No operations to report. 313 - Monday No operations to report. � r ° '� ,� _ � �� fi' ��F i 5/14/2013 - Tuesday ' � a No operations to report. w ®F T 6. THE STATE Alaska Gil and Gas alaservatiGil Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Op, Anchorage, Anchorage, Alaska 99501 -3572 Main: 907.279.1433 Fax: 907.276.7542 SCANNFV MAY 2 0 2013 Shane Bennett / L Operations Engineer V y `� Hilcorp Alaska, LLC D ✓ 3800 Centerpoint Drive Anchorage, AK 99503 Re: Kenai Field, Sterling 6Gas Pool, Kenai Deep Unit 2(21 -8) Sundry Number: 313 -220 Dear Mr. Bennett: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster Chair DATED this / day of May, 2013. Encl. ti . E C°" 7 STATE OF ALASKA .�� ,,,," r , ALASKA OIL AND GAS CONSERVATION COMMISSION `' �'u APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AO („,,1 „,11. ,. `. i. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ID - Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. ❑ 7. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: 1- i;lcorp Alaska, LLC Exploratory ❑ Development el k 168 -049 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: 3800 Centerpoint Drive, Anchorage AK, 99503 50 -133 -20121 • 0 0 — . C.49 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No ❑ KENAI DEEP UNIT 2(21 -8) • 9. Property Designation (Lease Number): 10. Field /Pool(s): FEDA028142 t . KENAI FIELD / STERLING 6 GAS - 1'i. PRESENT WELL CONDITION SUMMARY 1 otal Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): • 10,522 • 9,885 .` 8,432' 7,796' 10,477 10,477 (Fill) F Casing Length Size MD TVD Burst Collapse Structural Conductor 58' j_ 20” 58' 58' Surface 1,317' 1 13 -3/8" 1,317' 1,291' 2,730psi 1,130psi Intermediate 6,027' 9 -5/8" 6,026' 5,418' 5,750psi 3,090psi Production Liner 4,701' 7" 10,522' 9,898' 8,160psi 7,020psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): . See Attached Schematic See Attached Schematic 3 -1/2" N -80 7,809 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker SAB Packer and N/A - 7,683(MD)/7,048(TVD) and N/A 12. Attachments: Description Summary of Proposal 0 , 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch IO . Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 0 .1 '7 14. Estimated Date for 15. Well Status after proposed work: t � ' Y Commencing Operations: 4/8/2013 Oil ❑ Gas , ,, �1 r a j t W DSPL ❑ Suspended 1� L,J( 15. Verbal Approval: Date: ',5 - . / 3 WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: 4;1 I f GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is are and correct to the best of my knowledge. Contact Shane Bennett Email sbennettta'�,hilcorp.com iPrinted Name Benn Title Operations Engineer .Signature A '.:ji..,' r.t Phone 907-777 -8425 Date 5/6/2013 COMMISSION USE ONLY :Amditions of approval: Notify Commission so that a representative may witness Sundry Number: , 3(3 - 2•2X ! ug Integrity Lit/ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ i Other: I. 4 "6( . , w &IL c-e RBDMS MAY 1 '71013 Spacing Exception Required? Yes ❑ No Li Subsequent Form Required: // _ 1 APPROVED BY Approved by: (ac-/f ` � l�l� COMMISSIONER THE COMMISSION Date: / ..../3 r� • ' 7 M Submit Form and -) Form 10 -403 ( vised 10/2012) Approve is t' v li f r nths from the date of approval. / -` Attachments in plicat • • RWO Sundry Well: KDU 02 Hhicoro Alaska, L() Date: 5/5/2013 Well Name: KDU 02 API Number: 50- 133 - 20541 -00 -00 Current Status: Online Leg: N/A Estimated Start Date: May 3, 2013 Rig: Various Reg. Approval Req'd? 10 -403 Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts 777 -8398 Permit to Drill Number: First Call Engineer: Shane Bennett (907) 777 -8425 (0) (325) 203 -7487 (M) Second Call Engineer: Chris Myers (907) 777 -8333 (0) (907) 398 -9955 (M) AFE Number: Current Bottom Hole Pressure: —1,350 psi Extrapolated from SBHP on 10 -15 -2010 Maximum Expected BHP: —1,350 psi @ 7600' TVD Extrapolated from SBHP on 10 -15 -2010 Max. Anticipated Surface Pressure: —1,100 psi (Based on 0.03 psi /ft gas gradient) Brief Well Summary RIH with 6" tapered mill and scraper assembly in prep for running packers on injectivity test. Tag @ 7,933' RKB (top perfs) and unable to pass. RIH with 6" tapered string mill and 6" blade mill on 2 -7/8" pipe. Tag @ 7,928'. Mill through tight spot and drop 15' to next tight spot, continued milling. Currently at 7,952' (bottom of perfs) and losing —12 bbl /hr fluid since starting milling. Made it to 7,952' (bottom of top set of perfs), 6" blade mill and tapered watermelon mill assembly. Blade mill showing wear indicating collapsed casing, worn —1" on outside edge. Tapered mill had no wear. Washed to 7,900' and tagged fill. RIH mule shoe @ 7,962' MD RKB (mill tagging @ 7,955'). Begin putting WOB and lost returns, PU and regain returns. Circulated bottoms up, with large size coal, sandstone, cement, and metal filings to surface. RIH with 1.75" RS, 10' stem, KJ, OJ, LSSJ, and 4.25" GR to 7,929' MD WLM and sat down. RIH with same tool string, 3.80" centralizer, and 3.50" LIB. Tag @ 7,931', spanged down 2x and wouldn't fall. Suspend well. Summary Procedure 1. RU cement equipment, PT lines to 2,500 psi. 2. PUMU / Halliburton EZ Drill cement retainer on 2 -7/8" pipe to 7,861'! 3. Squeeze Tyonek perfs with 37 sacks of Class G + additives, 15.80ppg, 1.15 Yield, (7,911' - 7,951', 7,973'- 7,992', 8,220'- 8,262'). 4. PUMU HES cement retainer, TIH to ±7,863', TOC note depth. �1_� e 1 151) "`- 5. PU tn1921', set retainer, sting out PU to 5,751' (70' above shoe at 5,821'), pump 170' of cement, 58 sacks Class G + additives, 15.80ppg, 1.15 Yield. 6. WOC 24 hours. 227. PUMU HES cement retainer, TIH to ±5,751', TOC note depth. B. PU to 5,385', (120' below S. Pool 6 BP) set retainer, PT below retainer to 1,500 psi, if good. 9. Sting out PU to 5,049' (70' above S. Pool 6 TP); pump 190' of cement, 130 sacks Class G + additives, 15.80ppg, 1.15 Yield. 10. WOC 24 hours. 11. TIH to ±5049', with 2 -7/8's work string tag TOC, note depth. 12. LD around 2,000' of WS singles PT casing to 2,500psi, chart for 30 minutes, if good LD work string. 13. ND BOP TIH with 2,000' of 3 -Y2" tubing for kill string. 14. Land tubing in hanger. 5 8 P✓ / /J/D Bo 15. NU tree. gr. c_ / 4 PV eL."' 16. RD MOB to KBU 33 -06. • • • RWO Sundry Well: KDU 02 Hilcorn Alaska, LU Date: 5/5/2013 Attachments: 1. As -built Well Schematic 2. Proposed Well Schematic 3. BOP Schematic • KDU 2 • API: 50- 133 -20121 AOGCC: Pad 41 -7 Kenai Gas Field RT -G RT -G L L MARATHON 405' FNL, 4381' FWL Sec. 7, T4N, R11 W, S.M. Lift threads: ? ?? Ai l Tree cap: 4 -3/4" Otis (on dual tree) Drivepipe 20" @ 53' 13 - 3/8 ", 54 5#, J -55, STC csg @ 1317' Cmt w/ 650 sks of class "G" ■ Tubing String - 3 -1/2 ", 9.2 #, N -80, Butt Mod 9 - 5/8 ", 40 #, N -80 "seal -lock" csg @ 6027' Cmt w/ 700 sks of class "G" through shoe Camco sidepocket injection mandrel @ 984' X. i t & w/ 300 sks thru DV tool @1918' - injection valve installed 11/24/95 J/ Baker CMO Sliding Sleeve @ 7668' _ I ` � , Top of 7" TIW Hanger @ 5821' ID= 2.813" (closed 11/21/95) 1 , - Liner Baker K- Anchor @ 7681' �— J.-', 7" N -80 29# BTC Baker SAB Packer @ 7683' El nz 5821'- 10,522' Cmt w/ 1000 sks of class "G" X- nipple @ 7734' ID = 2.813" XN- nipple @ 7807' ID = 2.750" Wireline Re -entry Guide @ 7809' Coil Tubing Velocity String 1.75" OD, 0.125" WT coil tubing, I Hung from Weatherford PCH packer @ 300' '4 Minimum ID = 1.300" Landing nipple at end of coil @ 7,975' ActiveTyonek Perfs I no - ID = 1.265" 12 -1/2" HC, 6spf) _ 72 -8: 7911' -7951' (3/18/96) C 73 -1: 7973' -7992' (3/18/96) =„ 75-8: 8220' -8262' (11/29/95) C Fill tagged @ 8396' WLM 7/13/96 Al Isolated Perfs 8484' WLM 7/28/99 5119' -5120' (sgz'd 11/95) 8200' WLM 5/7/03 5128' -5138' (sgz'd 11/95) 8076' WLM 5/19/04 5190' -5170' (sqi d 11/95) 8268' WLM 8/9/04 5235-5265' (sgz'd 11/95) 8245-8255' (sgz'd 11/95) CT Cln Out to 8662' CTM 9/29/04 9510' -9522' (8/13/68) c Fill w/I tagged @ 8432' KB 10/15/10 9558' -9588' (8/13/68) ,,_- 9854-9874' (sqi d 8/4/74) __.. 9884-9910' (sgz'd 8/4/74) - 9919' -9920' (sgid 8/4/74) Cmt Retainer @ 9325' (11//8/95) 10006' -007' (7/27 /742) _ Baker Packer @ 9500' (8/18/74) 10028' -036' (8/13/68) _ Junk Retainer @ 9744' (8/9/74) 10080'- 092' (8/13/68) Cmt Retainer @ 9750' (8/3/74) Cmt Retainer @ 9950' (8/3/74) Junk Retainer @ 10,436' (8/1/74) I PBTD - 9325' TD - 10,522' Well Name & Number: KDU 2 Lease: Pad 41 -7, Kenai Gas Field County or Parish: Kenai Peninsula Borough State: Alaska I Country. USA Perforations: (MD) Tyonek (TVD): Angle @KOP and Depth: Angle /Perfs: KOP TVD: Date Completed: RKB: Prepared By Mike Sulley Last Revision Date: 10/15/2010 14 • • Kenai Gas Field Well: KDU 0 PROPOSED Last Compl eted: 8 /21/1968 HHiacorp Alaska, LLC PTD: 168 -049 CASING DETAIL RKB: MSL = 107' Size Type Wt/ Grade/ Conn ID Top Btm I 20" Conductor N/A Surf 58' ` 20 ",j 13 -3/8' Surface 54.5 / J -55 / STC 12.615 Surf 1,317' 9 -5/8" Intermediate 40 / N -80 / Seal Lock 8.835 Surf 6,027' 7" Liner 29 / N -80 / BTC 6.184 5,821' 10,522' TUBING DETAIL 3 -1/2" 1 Tubing 9.2 / N -80 / Butt Mod 2.992 Surf ±2,000' 13 -3/8" JEWELRY DETAIL No Depth Item 1 ±5,385' Cement Retainer q_ 7 $(, ( r TOC @ ±49 2 ±5,921' Cement Retainer , 3 9,485' Cement Retainer -' ._ r- ?> yS ACTIVE PERFORATION DETAIL TOC @ +5,750' Sands Top (MD) Btm (MD) Top (TVD) Btm FT Date Status 9-5/8" c ti (TVD) JO UT/72 -8 7,911' 7,951' 7,276' 7,280' 40 Squeeze 3/18/1996 , UT/ 73 -1 7,973' 7,992' 7,338' 7,357' 19 Squeeze filt4 . Z � QZ` UT/75 -8 8,220' 8,262' 7,584' 7,626' 42 11/29/1995 Squeeze 1 ISOLATED PERFORATION DETAIL 5,119' 5,120' 4,538' 4,539' 1' Sterling Pool 6 5,128' 5,138' 4,546' 4,556' 10' 5,170' 5,190' 4,586' 4,605' 20' Nov -95 Squeezed 5,235' 5,265' 4,648' 4,676' 30' Upper Ty /Bel 8,245' 8,255' 7,609' 7,618' 10' 9,510' 9,522' 8,874' 8,886' 12' 8/13/1968 Squeeze TOC@±7,861' 9,558' 9,588' 8,922' 8,952' 30' 9,854' 9,874' 9,2 9,238' 20' f 9,884' 9,910' 9,248' 9,274' 26' 8/4/1974 Squeezed T onek Collapsed* 7PGj y 9,919' 9,920' 9,283' 9,284' 1' Casing@ 10,006' 10,007' 9,370' 9,371' 1' 7/27/1974 ±7,955' 10,028' 10,036' 9,392' 9,400' 8' 8/13/1968 Isolated _ 10,080' 10,092' 9,443' 9,455' 12' 8/13/1968 OPEN HOLE / CEMENT DETAIL 13 -3/8" Cmt w/ 650 sks of class "G" 9 -5/8" Cmt w/ 700 sks of class "G" through shoe& w/ 300 sks thru DV tool @1918' 7" Cmt w/ 1000 sks of class "G" 3 4 TD = 10,522' PBTD = 10,477 Created By: TDF 5/6/2013 • • , ‘ H Ninilchik Unit 2013 BOP Stack xi !n,rp Alaska, Knight Oil Tools Rental W. 02/05/2013 Ninilchik Unit KDU -02 Cloverleaf #4 BOP i 3.98' Hydril GK 11' -5000 111 111 111 111111 111 1 1f t I!t t!E _ ciw -L MAME 2 7/8 -5 variables 4.54' 0 ® * ' ® ® - r - •I 1 , " - _ Blind (fl 111 111 111 111 OS 0. ' Choke and Kill valves 2 7/0. - A .�\1 6 1 �tJ` 21/1610M 7 /7s sM 4,4_ 0 �\\'�6 On One HCR 1111 — F 11111111111111111 2.00' P 0 rill is I a Y$ ' �;, - ' °' iIi tit Mai tii ,; r .- • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Sunday, May 05, 2013 9:12 AM To: Shane Bennett - (C) Cc: Keith Elliott; Chris Myers; Tom Fouts; James Ostroot - (C); Jeremy Mardambek Subject: RE: KDU 02 Sundry with cement data Shane, You have verbal approval to proceed with the plugs as you propose to Suspend ( not P & A) Well KDU 02. Please get the paper copy of the sundry procedure to me as soon as you can on Monday. I don't see any other alternative based on the collapsed casing to go ahead and set plugs to secure well for eventual Rotary sidetrack. Guy Schwartz 907 -444 -3433 From: Shane Bennett - (C) [sbennett@hilcorp.com] Sent: Saturday, May 04, 2013 7:50 PM To: Schwartz, Guy L (DOA) Cc: Keith Elliott; Chris Myers; Tom Fouts; James Ostroot - (C); Jeremy Mardambek Subject: KDU 02 Sundry with cement data N. Al.' (11,'\ 'SY Shane Bennett - (C) Operations Engineer — Alaska 0 (907) 777 -8425 C (325) 203 -7487 H (325) 643 -2401 1 • • Schwartz, Guy L (DOA) From: Shane Bennett - (C) <sbennett@hilcorp.com> Sent: Friday, May 03, 2013 8:09 PM To: Schwartz, Guy L (DOA) Cc: Keith Elliott; Chris Myers; Jeremy Mardambek; Tom Fouts; James Ostroot - (C) Subject: KDU 02 Guy I left a message on your work and cell on the KDU -02. As to the workover, we are going to P&A this well. James Ostroot (WSM) gave twenty -four notice on the AOGCC website to pump cement 5/4/2013, at 7:00 p.m. Pump schedule is to sting into top at 7,861, with bottom at 7,955' a total of 94' in 7" Liner 29 # /N -80. Volume calls for 19.60sks of cement, we plan to pump 23.52sks. I will try and reach you again in the morning or you can reach me at 325 - 203 -7487, if you want to call me, thanks. Shane Shane Bennett - (C) Operations Engineer — Alaska O (907) 777 -8425 C (325) 203 -7487 H (325) 643 -2401 • • • Davies, Stephen F (DOA) From: Shane Bennett - (C) [sbennett @hilcorp.com] Sent: Thursday, May 16, 2013 4:40 AM To: Bettis, Patricia K (DOA); Davies, Stephen F (DOA); Schwartz, Guy L (DOA) Cc: Jeremy Mardambek; Keith Elliott; Chris Myers; Joey Hensley; Pete Iverson Pp Subject: RE: Application for Sundry Approval: Kenai Deep Unit 2 (21 -8) Subject: KDU 02 will be utilized as a future sidetrack opportunity to test the Tyonek D sands and deeper gas sands recognized in the logs in offset wells. Due to the rig schedule this work will likely be done in 2014 and is contingent on the success of other deep pool gas tests currently in the rig work over queue through 2013 and into 2014. Hilcorp Alaska, LLC Shane A. Bennett Operation Engineer 0 (907) 777 -8425 C (325) 203 -7487 H (325) 643 -2401 From: Bettis, Patricia K (DOA) [patricia.bettis@alaska.gov] Sent: Wednesday, ,May 08, 2013 1:06 PM To: Shane Bennett - (C) Subject: Application for Sundry Approval: Kenai Deep Unit 2 (21 -8) Good morning Shane, Please provide information on what the well long term plans are. 20 AAC 25.110(a) requires Hilcorp to submit in writing the justification for suspending a well versus plugging and abandoning. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793 -1238 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 1 • • Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Wednesday, May 15, 2013 4:37 PM To: Shane Bennett - (C) Subject: FW: Application for Sundry Approval: Kenai Deep Unit 2 (21 -8) Shane, I'm reviewing Hilcorp's Sundry Application for Kenai Deep Unit 2 (21 -8). Could you please provide the justification that Patricia requested, below? Thanks, Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907 - 793 -1224 Fax: 907 -276 -7542 From: Bettis, Patricia K (DOA) Sent: Wednesday, May 08, 2013 10:07 AM To: 'sbennett@hilcorp.com' Subject: Application for Sundry Approval: Kenai Deep Unit 2 (21 -8) Good morning Shane, Please provide information on what the well long term plans are. 20 AAC 25.110(a) requires Hilcorp to submit in writing the justification for suspending a well versus plugging and abandoning. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793 -1238 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 Patricia Bettis at (907) 793 -1238 or patricia.bettis@alaska.gov. 1 Hilcorp Alaska, LLC Post Office Box 244027 Anchorage, AK 99524 3600 Centerpoint Or Suite 100 Anchorage, AK 99503 Phone: 907/777-8300 Fax: 907/777-8560 April 29, 2013 Re: (Milling of tight spots from 4,380' to 4,417' on the KDU - 02) PfD -CO 10 Guy while TIH w/ lip guide on OS to retrieve baker packer encountered tight spot at 4,380'. PU, TIH to 4,380' thru 4,417', several tight spots. TOH, RIH w/ mill to 4,380" thru 4,417', rotated and worked up and down until no drag. TOH changed lip guide on OS, RIH to 7,642', released anchor packer, TOH, recovered rest of fish, wl re-entry guide, 2-x nipple, baker k packer, sliding sleeve, pups and 3.5" cut piece tubing w/ 8 5/8's round nose mill. RIH to 7,936', unable to burn over packer, TOH, RIH w/ spear and same BHA, spear fish, TOH. At this point we are going to run Storm Packer Assembly, set the plug @ 4,430' and PU and set packer @ 4,360', test and chart casing to 1,000psi for 30 minutes, with a good chart we will then start getting injection rates from the Pool 6 perfs, by set for squeeze job. Please feel free to contact me with any questions you may have. Sincerely, HILCO ALASKA, LLC Shane Bennett Operation Engineer 907-777-8425 Integrity Urgency Ownership Alignment Improvement Post Office Box 244027 Anchorage, AK 99524-4027 llilrorp Alaska, LLC 3800 Centerpoint Drive Suite 100 Anchorage, AK 99503 Phone: 907/777-8300 April 29, 2013 Fax: 907/777.-8301 Re: KDU 02 Casing Test and Injection Rates James please pick up a RTTS, from Halliburton for the procedures. 1. RIH to 6,200' and set RBP, it will be in the 7", test to surface at 1,000psi for 30 minutes, use charter for graph. If good go on to next steps, if please call myself or Chris Myers. 2. Drop down and test bottom perfs (1St Test Set), 8,220' to 8,262'(42'). 3. Pick up and test middle perfs (2"d Test Set), 7,973' to 7,992'(19'). 4. Pick up and test top perfs (3rd Test set), 7,911' to 7,951' (40'). 5. Note the injection rate and pressure of each set of perfs. Please feel flee to contact me with any questions you may have. Sincerely, HILCORP ALASKA, LLC Shane Bennett Operation Engineer 907-777-8425 KDU 02 History IP Oil IP Gas IP H2O FTP Ck Stimulation Perlis 7.91 V to 7,951- (400 Ord Test Set 7 911' to 7 951' 40' 7,97V to 7 992' 19' 8,22V to 8,262- 42' 2nd Test Sell 7 973'to 7,99Z 19' 1st Test Set 8 220' to 8,28T 42' Testing Procedure i st Test Set 8,2W to 8,262(42') Set RBP LM 8,272'+/ - Set PKR ft 8.206+/ - (2nd Test Set 7 973' to 7,992'(19* Set RBP A 8,00Z+/, 00 +/- Set PKR A ISet 7,950+1 - Ord Test Set 7.911' to 7,951'(40'1 Set RBP a 7,966+/ - Set PKR 0 7 900+1- Attachement #1 PBTO 9.325' TO 10522' RBP 6,200' in 7" API No: 50.133.20121 Hole Size: 17.5" Surf csg 133/6"54.50 J55 Set a 1317' Cement w/ 650 Circ: Yes Hole Size: 11" Inter. csg 9 518" 400 N80 Set (rD 6027 Cement w/ 700500th, Mat91a Circ: NOTE INJECTION RATES and PRESSURE In'ection Rates 7,91 Vto 7 951_bpm @ _psi 17,97T to 7,992' 1 _bpm @ _psi 18,22(Y to 8,262- 1 _bpm Q _psi Hole Size: Prod. Csg 7" L N80 290 R80 Set f® 10,522 Cement w/ 1000 Circ: Stege tool (n Regg, James B (DOA) From: Bobby Adams [badams@hilcorp.com] Sent: Wednesday, April 24, 2013 7:30 PM To: DOA AOGCC Prudhoe Bay Cc: Chris Myers Subject: test tiw valve Used TIW valve to shut tbg in . Well was out of balance. Will test tiw valve when I use 2 7/8" test jt. Date= 4-24-13 at 6:00 am. Well/location/ ptd #= kenai deep unit 2(21-8), kenai field, sterling 6 gas pool Rig= cloverleaf #4 Operator contact= bobby adams Operation summary, including events leading up to bope use = well was out of balance and tbg burped stabbed tiw and kill tbg w/ 20 bsw. No pressure on csg. Bope were not used just tiw valve. Bope used = no Reason for bope use= did not use. Action taken/to be taken bope test= will test tiw valve when bope are tested for 2 7/8" work string. Had bope test On 4- 22-13. 1 MINIMINI■11■ • OF T71 Alaska Oil and Gas w \�� j THE STATE s � F = °fALAS� Conservation Commission _ = *h „ GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 Off ALAS" Main: 907.279.1433 Fax: 907.276.7542 Shane Bennett SCANNED APR 1 b 2013 Operations Engineer Hilcorp Alaska, LLC J Q +, 3800 Centerpoint Drive, Suite 100 (� 0 Anchorage, AK 99503 Re: Kenai Field, Sterling 6 Gas Pool, Kenai Deep Unit 2(21 -8) Sundry Number: 313 -174 Dear Mr. Bennett: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy ' . Foerster Chair DATED this //14-Clay of April, 2013. Encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS � , 20 MC 25.280 1 1 Type of Request: Abandon ❑ . Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations 0 • Perforate ❑ Pull Tubing El • Time Extension � ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. Gbmpletoj 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: 5 `flN•6 Hilcorp Alaska, LLC Exploratory ❑ Development El • 168 - 049 3. Address: . • Stratigraphic ❑ Service ❑ 6. API Number. • 3800 Centerpoint Drive, Anchorage AK, 99503 50 - 133 - 20121 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No ❑✓ /' 4 i KENAI DEEP UNIT 2(21 - 9. Property Designation (Lease Number): 10. Field /Pool(s): FEDA028142 • KENAI HELD / STERLING 6 GAS 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): 10,522 / 9,885 - 8,432' 7,796' 10,477 10,477 (Fill) Casing Length Size MD TVD Burst Collapse r Structural _. Conductor 58' 20" 58' 58' Surface 1,317' I 13 -3/8" 1,317' 1,291' 2,730psi 1,130psi r Intermediate 6,027' 9 -5/8" 6,026' 5,418' 5,750psi 3,090psi • Production " Liner 4,701' 1 7" 10,522' 9,898' 8,160psi 7,020psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 3 - 1/2" N - 7,809 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker SAB Packer and N/A 7,683(MD)/7,048(TVD) and N/A 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/8/2013 Oil ❑ Gas WDSPL ❑ Suspended ❑ , • i 6. Verbal Approval: Date: N/A WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: N/A GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Shane Bennett Email sbennett c hiIcorp.com Printed Name - Benne_ Title Operations Engineer t ignature /// ` /Al, _ Phone 907- 777 -8425 Date 4/5/2013 I COMMISSION USE ONLY i ' +T onditions of approval: Notify Commission so that a representative may witness Sundry Number: I • 313 - 04 i Flug Integrity ❑ BOP Test ' Mechanical Integrity Test ❑ Location Clearance ❑ IOther: RRDMS APR 1 2 201 3O6o Psi:. ,Q o !° 1��se Spacing Exception Required? Yes ❑ No [( Subsequent Form Required: l — YQ le / APPROVED BY H pproved by , iL /2_ COMMISSIONER THE COMMISSION Date: -.'-/ / ../.j Submit Form and ^ or t Rol ( aid /�o A pproved application is valid for 12 months from the date of approval. Attachm in Dup cat t 7 • • , RWO Sundry Well: KDU 02 Hilcorp Alaska, LI) Date: 4/4/2013 �c. , 3. I 2,/,_ 04, (iii Well Name: KDU 02 API Number: 50- 133 -20 -00 Current Status: Online Leg: N/A - Estimated Start Date: April 24, 2013 Rig: Various Reg. Approval Req'd? 10 -403 Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts 777 -8398 Permit to Drill Number: First Call Engineer: Shane Bennett (907) 777 -8425 (0) (325) 203 -7487 (M) Second Call Engineer: Chris Myers (907) 777 -8333 (0) (907) 398 -9955 (M) AFE Number: Current Bottom Hole Pressure: -1,350 psi Extrapolated from SBHP on 10 -15 -2010 Maximum Expected BHP: -1,350 psi @ 7600' TVD Extrapolated from SBHP on 10 -15 -2010 Max. Anticipated Surface Pressure: -1,100 psi (Based on 0.03 psi /ft gas gradient) Brief Well Summary KDU 02 is currently a single Upper Tyonek producer with a 1.75" coiled tubing velocity string and is currently flowing 0.6 MMSCFD in the low pressure system at Kenai Gas Field. KDU 02 was originally drilled in 1968 as a selective Tyonek D -2 and D -3, D -4 sands producer. By 1974, the D -3 & 4 sands started producing some volume of water and along with gas. In 1974 A RWO was performed to make the well a dual D -2 /Pool 6 well. During the 1974 RWO the Upper Tyonek was perforated and tested with a reservoir pressure of 4,050psi. The un- stimulated rate was too low to justify the complicated completion to flow all three targets so the well was completed as a dual D -2 sand /Pool 6. In 1995 the D -2 sand and Pool 6 was abandoned in order to produce the Upper Tyonek sands tested in 1974. In 1995 the D -2 and Pool 6 were abandoned and one hundred feet of Upper Tyonek perforations were added and fracked in 1995 which has produced ever since. A 1.75" velocity string was added in 2004 in order to help keep the well unloaded. The current completion is a 1.75" velocity string inside of 3.5" tubing inside of 7" liner hung off at 5,821' MD off of 9 -5/8 "intermediate casing cased to surface. There is also 13 -3/8" surface casing. The goal of this RWO is to test the Tyonek D -5 and D -6 sands. A cased hole log will be run when the completion is removed to as deep as possible over all gas bearing zones in this well. Additional perforation targets will be I identified after the cased hole log is run. The tubing tail will be set so that there is enough clearance to test the D -2 through D -6 sands. / tb , `.( ° r 5u C Summary Procedure , i.h 1 tee. 1. RU Coiled tubing and test BOPs. �� r (if 2. Latch onto 1 -3/4" coiled tubing velocity string and pull on to coil reel. 3. RD Coiled tubing. 4. RU Slick line and set plug in nipple at 7,807' MD. 5. Pressure test plug set to 2,500psi. 6. RD Slick line. 7. RU Cloverleaf Rig 4. �� $' -1":- 8. Set two way check, ND Tree. �r si 9. NU BOP and pressure test BOP to 250psi low /3,000p high. 10. POOH with 3.5" and Baker SAB packer. 11. Patch or squeeze existing Upper Tyonek perforations at 7,911'- 7,951', 7,973'- 7,992' and 8,220' - 8,262' MD. ''----~ 7u14 ` 44.14 a . rili" /9 • • RWO Sundry Well: KDU 02 Hilcrora Alaska, LU Date: 4/4/2013 12. RIH and pull out cement retainer at 9,325' MD, Baker Packer w/ tubing tail at 9,500', junk retainer at 9,744', cement retainer at 9,750', and cement retainer at 9,950'. 13. Squeeze perforations at 9,510' — 9,522' and 9,558' — 9,588' MD. • 14. RU Slick line. 15. RIH with 3 -%2" gauge ring to junk retainer at 10436'. Mill if gauge ring drift fails. 16. RD Slick line. 17. RU Eline. 18. RIH with TMD3D Halliburton log. 19. RE Eline. 20. RIH with 3.5" completion setting tubing tail no lower than 9,440' MD. 21. Land tubing in hanger and set retrievable packer. 22. ND BOP and NU tree. Perforation targets will come after the TMD3D log is processed. PSLA Attachments: /3( 6 , 4 ,,4 1. As -built Well Schematic 2. Proposed Well Schematic 3. BOP Schematic • • Kenai Gas Field Well: KDU 02 SCHEMATIC Last Completed: 8/21/1968 Hileorp Alaska, LLC PTD: 168 -049 CASING DETAIL RKB: MSL = 107' Size Type Wt/ Grade/ Conn ID Top Btm 20",..1 20" Conductor 1 3 N/A Surf 58' 3/8' Surface 54.5 / 1-55 / STC 12.615 Surf 1,317' , 1 9 -5/8" Intermediate 40 / N -80 / Seal Lock 8.835 Surf 6,027' 1 7" Liner 29 / N -80 / BTC 6.184 5,821' 10,522' TUBING DETAIL 2 3 1/2" Tubing 9.2 / N -80 / Butt Mod 2.992 Surf 7,809' 1.75" Coil- Velocity 0.125 WT Surf 7,975' JEWELRY DETAIL No Depth Item 13 -3/8 "A 1 300' Weatherford PCH Packer 2 984' Camco Sidepocket Injection Mandrel - Installed 11/24/95 3 5,821' TIW Hanger 4 7,668' Baker CMO Sliding Sleave -10=2.813" Closed 11/21/95 5 7,681' Baker K- Anchor 3 6 7,683' Baker SAB Packer I 7 7,734' X- Nipple -ID= 2.813" 9 - 5/8" A ,'' , • 8 7,807' XN- Nipple - ID =2.750 , ', 4 9 7,809' Wireline Re -entry Guide 1 " 5 10 7,975' Landing Nipple at end of Coil IN _` 11 9,325' Cement Retainer 6 12 9,500' Baker Packer w/ Tubing Tail 13 9,744' Junk Retainer 111 14 9,750' Cement Retainer 7 15 9,950' Cement Retainer 16 10,436' Junk Retainer 8 17 10,477' Cement Plug 1 9 ACTIVE PERFORATION DETAIL 10 Sands Top (MD) Btm (MD) Top (TVD) (TVD) FT Date Status UT/72 -8 7,911' 7,951' 7,276' 7,280' 40 Open UT/73 -1 7,973' 7,992' 7,338' 7,357' 19 3/18/1996 Open UT/75 -8 8,220' 8,262' 7,584' 7,626' 42 11/29/1995 Open ISOLATED PERFORATION DETAIL 5,119' 5,120' 4,538' 4,539' 1' Sterling Pool 6 5,128' 5,138' 4,546' 4,556' 10' 5,170' 5,190' 4,586' 4,605' 20' Nov -95 Squeezed 5,235' 5,265' 4,648' 4,676' 30' Upper Ty /Bel 8,245' 8,255' 7,609' 7,618' 10' 9,510' 9,522' 8,874' 8,886' 12' 9,558' 9,588' 8,922' 8,952' 30' 8/13/1968 Isolated 9,854' 9,874' 9,218' 9,238' 20' TOF tagged@ 9,884' 9,910' 9,248' 9,274' 26' 8/4/1974 Squeezed 8,432' MD- 10/15/10 Tyonek 9,919' 9,920' 9,283' 9,284' 1' 10,006' 10,007' 9,370' 9,371' 1' 7/27/1974 =j,7 10,028' 10,036' 9,392' 9,400' 8' 8/13/1968 Isolated w; 11 10,080' 10,092' 9,443' 9,455' 12' 8/13/1968 12 14 OPEN HOLE / CEMENT DETAIL 15 13 -3/8" Cmt w/ 650 sks of class "G" 16 9 -5/8" Cmt w/ 700 sks of class "G" through shoe& w/ 300 sks thru DV tool @1918' AT" 17 7" Cmt w/ 1000 sks of class "G" 7" 4 1. TD = 10,522' PBTD = 9,325' Revised By: TDF 3 -21 -2013 • • Kenai Gas Field H Well: KDU 02 1 PROPOSED Last Completed: 8/21/1968 Hilcorp Alaska, LLC PTD: 168 -049 CASING DETAIL RKB: MSL =107' Size Type Wt/ Grade/ Conn ID Top Btm 3 20" Conductor N/A Surf 58' 20 J ` 13 3/8' Surface 54.5 / J 55 / STC 12.615 Surf 1,317' 9 -5/8" Intermediate 40 / N -80 / Seal Lock 8.835 Surf 6,027' 7" Liner 29 / N -80 / BTC 6.184 5,821' 10,522' TUBING DETAIL z 3 -1/2" Tubing 9.2 / N -80 / Butt Mod 2.992 Surf 7,809' 1.75" Coil- Velocity 0.125 WT Surf 7,975' JEWELRY DETAIL No Depth Item 13-3/8 1 9,385' Baker SAB Packer 2 9,405 X- Nipple - ID= 2.813" 3 9,485' Wireline Re -entry Guide 4 10,436' Junk Retainer ACTIVE PERFORATION DETAIL 9-50 A 4 Sands Top (MD) Btm (MD) Top (TVD) (WD FT Date Status UT/72 -8 7,911' 7,951' 7,276' 7,280' 40 Squeeze UT / 73 -1 7,973' 7,992' 7,338' 7,357' 19 3/18/1996 Squeeze UT / 75 -8 8,220' 8,262' 7,584' 7,626' 42 11/29/1995 Squeeze ISOLATED PERFORATION DETAIL 5,119' 5,120' 4,538' 4,539' 1' Sterling Pool 6 5,128' 5,138' 4,546' 4,556' 10' 5,170' 5,190' 4,586' 4,605' 20' Nov -95 Squeezed 5,235' 5,265' 4,648' 4,676' 30' UpperTy /Bel 8,245' 8,255' 7,609' 7,618' 10' 9,510' 9,522' 8,874' 8,886' 12' 9,558' 9,588' 8,922' 8,952' 30' 8/13/1968 Squeeze 9,854' 9,874' 9,218' 9,238' 20' Tyonek 9,884' 9,910' 9,248' 9,274' 26' 8/4/1974 Squeezed 9,919' 9,920' 9,283' 9,284' 1' 10,006' 10,007' 9,370' 9,371' 1' 7/27/1974 10,028' 10,036' 9,392' 9,400' 8' 8/13/1968 Isolated 10,080' 10,092' 9,443' 9,455' 12' 8/13/1968 OPEN HOLE / CEMENT DETAIL 13 -3/8" Cmt w/ 650 sks of class "G" 9 -5/8" Cmt w/ 700 sks of class "G" through shoe& w/ 300 sks thru DV tool @1918' 7" Cmt w/ 1000 sks of class "G" IL 1 2 3 tit43 I Dz .. DG) I Ea 4 T' fe 4 TD = 10,522' PBTD = 10,477' Created By: TDF 4/5/2013 • • • Kenai Gas Field KDU #2 04/05/2013 Iliknrp Alaska, 11(: Tubing hanger, CIW -DCB- Kenai Gas Field g er g KDU #2 FBB, 11 X 3 % EUE 8rd lift 133/8X95/8X31/2 and 3 % EUE susp, w/ 3" type H BPV profile, 6 1/4" EN, %" non continuous control line Tree cap Otis, 3 1/8 5M FE X 6 Otis Quick Union II .i. IR li. iiiiiiiiiiiiiiiiiiii IOW 11111 Valve, swab,WKM -M, 3 1/8 5M FE, HWO, T -24 a. i - 4? Valve, Wing, } G�' p VG -200, 3 1/8 5M FE, w/ ,, ,,, Axelson MHA oper, DD trim Tee, stdd, 3 1/8 5M X t 1III.I:J 0 31/85M _ . 1 4 P 1111 . 1111111 1TII PENII Valve, upper master, iit © Q , WKM -M, 3 1/8 5M FE, HWO, �� T 24 t � If1 141 IMP .fl i./ Valve, lower master, WKM -M, 3 1/8 5M FE, HWO, (o Q T -24 ® Adapter, CIW -FBB, 11 5M FE X li in 1 3 1/8 5M, prepped for 6 %" 4 - -- extended neck, 1 /2npt control line port •Bi • i it Tubing head, CIW- DCB, i Ili 13 5/8 3M X 11 5M, w/ 2- Valve, CIW -FC, 2 1/16 5M FE, 2 1/16 5M SSO, X- bottom ' - HWO, AA prep, 1 %2 VR profile I as r �[_ e a ,�)�' I-i• _,......_ 1 L it li,iim:g .... Casing head, Shaffer KD, 111 --' 1 13 5/8 3M X 13 3/8 SOW, w/ 2- 2" _ 2 'LP CIW ball valve LPO, ICI OR ' a I i. 1 { , Marathon Oil Company Alaska Business Unit Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 October 15, 2004 RECE\VED OE11 ~ '2004 Comì~1h~¡on Ala:;hn on ;); {\nt" i,jI ;i~e Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W ih Ave Anchorage, Alaska 99501 Reference: KDU 2 Dear Mr. Aubert: Enclosed is the 10-404 Report of Sundry Well Operations for Marathon well KDU 2. The proposed work to install a 1-3/4" coiled tubing lift was completed September 30th. This work was intended to combat erratic production and the continued need to blow the well down due to loading. I have also enclosed a daily operations report and an updated wellbore diagram for your review. If you have questions or need any additional information, I can be reached at 907- 283-1333 or bye-mail at DMTitus@MarathonOiLcom. Sin~.e.r.. elY~ .. ~ n~. ~~ J¡~Y Denise M. Titus Production Engineer Enclosures OR\G\NAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Performed: Alter Casing D Change Approved Program D 2. Operator Name: RepairWell U Pull Tubing D Operat. Shutdown D Plug Perforations U Perforate New Pool D Perforate D 4. Current Well Class: Development D Stratigraphic D StimulateU Other l;J Install V-string Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: ExploratoryD 168-049 Service D 6. API Number: 50-133-20121 Marathon Oil Company 3. Address: P. O. Box 196168, Anchorage, AK 6168 7. KB Elevation (ft): 99519- 9. Well Name and Number: 107' KB KDU2 8. Property Designation: 10. Field/Pool(s): Kenai Unit Beluga/Tyonek Pool 11. Present Well Condition Summary: Total Depth measured true vertical 10522 9885 feet feet Plugs (measured) Junk (measured) N/A N/A Effective Depth measured true vertical 9325 8689 feet feet Casing Structural Conductor Surface Intermediate Production Liner Length Size MD TVD Burst Collapse 58' 1317' 6026' 20" 58' 1317' 6026' 58' 1291' 5418' Not Cemented 2730 5750 Not Cemented 1130 3090 13-3/8" 9-5/8" 4701' 7" 10522' 9898' 8160 7020 Perforation depth: Measured depth: 8222-62,7973-92,7911-51 True Vertical depth: 7597-639,7350-92,7288-328 Tubing: (size, grade. and measured depth) 3-1/2" N-80 7809 Packers and SSSV (type and measured depth) Baker SAB Packer 7683 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 550 700 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations 1550 1620 15. Well Class after proposed work: Exploratory D Development 0 16. Well Status after proposed work: OilD Gas 0 WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service D Attached Contact Denise Titus GINJ D WINJ D WDSPL Isun~ Num~eJor N/A~C~. ~t: ~O Lf-~'"}{ " . D I Printed Name Denise M. Titus /' i i ,/ '1tItt;. II'-=:> ': ~ .. lit¡--' Signature A l ~~' I ¿j/ Title Production Engineer Phone 907.283.1333 Date 10/13/2004 Form 10-404 Revised 04/2004 OR\G\NAL Submit Original Only MARATHON OIL COMPANY Page 1 of 1 . Daily Maintenance/Repair Report Increase Production WELL NAME KB IGL 124 HR PROG TMD TVD [DFSO 1 DOLO IRPT#3 DATE KENAI DEEP UNIT 2 14.6 66.00 28-Sep-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Denise Titus cc 20858300 FIELD NAME RIG PHONE MOC WI NRI I DAILY WELL COST I CUM WELL COST KENAI 100.0000 15,000 () 27,518 () STATEIPROV COUNTY/OTHER LAST CASING 1 NEXT CASING 1 LEAKOFF Alaska (â) 0 (in) (â) 0 (ft) CURRENT STATUS @ 6AM 124 HR FORECAST CT rigged up and readv for cleanout Cleanout casino Drior to hanooff OPERATION COMMENTS Rig up on KDU 2 to perform CT clean out and hangoff SAFETY ~I" .u A"'" MANHRS WORKED I ~CCIDENT TYPE I LAST SAFETY MTG IBOP PSI TEST LAST STOP CARD AUDIT I ~EGULATORY INSP? I LAST RIG INSPECTION 41.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: OPERATIONS SUMMARY FROM TO HRS FROM TO SUB PHASE OP SUBOP TRBL DESCRIPTION 10:00 17:00 7.00 CLNOUT RURD- COIL Move in BJ CT unit w/1-3/4" workstring. Spot 1-3/4" HO string next to work reel. RU MOC flowback iron using BJ services choke manifold. Stab pipe and rig back for AM. PERSONNEL DATA POB @ 06:00: COMPANY I SERVICE I NO. I HOURS II COMPANY T SERVICE I NO. I HOURS Marathon I Supervision I 1 I 8.00 II Pollard Wireline I Slickline I 31 33.00 ~I LAST BOP TEST: LAST CASING TEST: NEXT BOP TEST: SIZE ID I SHOE TEST MAX SICP I MD I TVD I WT I GRADE I BURST Printed: 10/1412004 2:29:49 PM MARATHON OIL COMPANY Page 1 of 1 Daily Maintenance/Repair Report Increase Production WELL NAME KB IGL 124 HR PROG TMD TVD IDFSO ¡DOLO IRPT#4 DATE KENAI DEEP UNIT 2 14.6 66.00 29-Sep-2004 SUPERVISOR RIG NAME & NO. AUTH MD was SAPIWBS COST Denise Titus cc 20858300 FIELD NAME RIG PHONE MOCWI NRI I DAILY WELL COST I CUM WELL COST KENAI 100.0000 37,1000 64,618 () STATEIPROV COUNTY/OTHER LAST CASING I NEXT CASING I LEAKOFF Alaska @ 0 (in) @ 0 (ft) CURRENT STATUS@ 6AM 1,24 HR FORECAST Casing washed to 5662' CTM Hane off velocitv strine. OPERATION COMMENTS Washed casing without difficulty to 8662' only tagging fill briefly at 8500' CTM. Circulate hole clean with fluid leaving 6% KCI and 470psi N2 pressure on the well. SAFETY ARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG IBOP PSI TEST I LAST STOP CARD AUDIT I ~EGULATORY INSP? I LAST RIG INSPECTION 41.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: OPERATIONS SUMMARY FROM TO HRS FROM TO SUB PHASE OP SUBOP TRBL DESCRIPTION 07:00 07:30 0.50 AF CLNOUT SAFETY MTG- Arrive at gas field. Obtain peffi1it. Hold safety and awareness meeting. 07:30 09:00 1.50 AF CLNOUT RURD- COIL Start up equipment. PU injector head. Roll friction reducing into fluid supply tank with vac truck. 09:00 12:00 3.00 TA CLNOUT TEST- BOPE MSCT Load CT. After 30bbl, pressure up and no returns to tank. Nozzle plugged. Remove BHA and circ CT to tank via flowcross. Cleanout and reinstall BHA. Pressure test pipe rams to 250/4500psi. 12:00 15:00 3.00 AF CLNOUT ,UNPUL COIL RIH w/ CT wash nozzle. Begin pumping N2 and fluid at 1.5 bpm w 750 scfm N2 at about 6000'. Reach tubing tail and continue washing. Getting good returns at surface. Started to see gray gritty returns laden with formation material with nozzle at about 8300'. Tag at 8500' CTM. Easily wash off. Continue to 8662' CTM. Decide sufficient rathole and discontinue washing. 15:00 16:00 1.00 AF CLNOUT CIRC- CFLD Drop ball to engage upward jetting tornado nozzle. CBUx1 still pumping 1.5bpm w/750 scfm. Returns clean. 16:00 17:30 1.50 AF CLNOUT ,UNPUL COIL PUH pumping same. Shut down N2 at 5000' and continue out of hole blowing CT dry with N2. SI returns when water flowback ceases. 17:30 18:30 1.00 AF CLNOUll LOWm COIL At surface with CT. 470psi N2 pressure trapped on well. Close swab valve and bleed down CT string. Total fluid pumped 270bbl. Recovered -240bbl. 18:30 20:00 1.50 AF CLNOUT RURD- COIL Rig back injector head. Secure well for night. Unstab workreel pipe and stab hangoff string in preparation for tomorrow's velocity string hangoff. PERSONNEL DATA POB @ 06:00: COMPANY I SERVICE I NO. I HOURS II COMPANY I SERVICE I NO. I HOURS Marathon I Supervision I 1 I 8.00 II Pollard Wireline I Slickline I 31 33.00 .... LAST BOP TEST: LAST CASING TEST: NEXT BOP TEST: SIZE ID I SHOE TEST MAX SICP I MD I TVD I WT I GRADE I BURST Printed: 10/14/2004 2:29:03 PM MARATHON OIL COMPANY Page 1 of 2 Daily Maintenance/Repair Report Increase Production WELL NAME KB [GL 124 HR PROG TMD TVD IDFSO ¡DOLO IRPT#5 DATE KENAI DEEP UNIT 2 14.6 66.00 30-Sep-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST "Denise Titus cc 20858300 FIELD NAME RIG PHONE MOC WI NRI 1 DAILY WELL COST I CUM WELL COST KENAI 100.0000 48,800 () 113,418 () STATEIPROV COUNTY/OTHER LAST CASING I NEXT CASING ILEAKOFF Alaska lID 0 (in) lID 0 (ft) CURRENT STATUS @ 6AM 124 HR FORECAST Velocitv strine installed. Flow well to svstem OPERATION COMMENTS Hangoff 1-3/4" velocity string to a depth of 7975'. Packer at 300'. :oiat-t- I y' ~I ............ MANHRS WORKED I ~CCIDENT TYPE I LAST SAFETY MTG IBOP PSI TEST I LAST STOP CARD AUDIT I ~EGULATORY INSP? I LAST RIG INSPECTION 41.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Footing in wet conditions OPERATIONS SUMMARY FROM TO HRS FROM TO SUB PHASE OP SUBOP TRBl DESCRIPTION 07:00 08:00 1.00 AF :;MPRUN SAFETY MTG- Sign in obtain work permit. Hold safety and procedure meeting. Elect to re-pig hangoff pipe due to yesterday's nozzle plugging with work string. Discuss need to be aware of footing when working in rain and snow. 08:00 09:00 1.00 AF :;MPRUN RURD- COIL Warm up equipment and make up pig catcher and injector head. Pwh=1050 (built from 470 psi previous night) 09:00 11:30 2.50 TS :;MPRUN PIG- LINE Pump 27 bbl through hangoff string. Did not see pressure up as expected. Checked pig catcher to find no pig. Pig is still in launcher. Re-pig line successfully. 11:30 12:15 0.75 AF :;MPRUN PULD- BHA- Make up hangoff BHA including CT connector, 10' straigt bar, xo, nipple for 1.188 KEP plug, XO, and pump off sub w/ plug and re-entry guide. 12:15 12:45 0.50 AF CMPRUI\ TEST- BOPE Shell test and test back of connection through kill line to 250/1 OOOpsi. 12:45 14:30 1.75 AF þMPRUfI RUNPUL COIL RIH w/ hangoff string to 8200'. All perfs are clear. PUH to 7675' in preparation to cut CT. 14:30 15:30 1.00 AF þMPRUfI CUT- COIL Close rams and bleed off pressure above. Hold safety meeting to discuss procedure to walk up injector head. Break lubricator connection and walk injector head up CT. Open inner reel valve to ensure no pressure. Cut weep hole in CT to ensure no interior pressure. Cut CT and swing injector head to ground. 15:30 16:45 1.25 AF þMPRUI\ PULD- PKR- Make up Weatherford CT connector and packer to pipestub. MU MHA with disconnect to injector head CT. PU injector head and connect MHA to packer. MU lubricator and pull test. Good test to 90001bs. Break lubricator to inspect and prepare connections for running. MU lubricator and equalize pressure across pipe rams. 16:45 17:00 0.25 AF þMPRUI\ "UNPUL COIL Open pipe rams and RIH w/ velocity string, packer, and disconnect RIH 300' to hangoff depth of 7975' with well open to gas buster. Well is flowing gas and carrying water steadily to tank at 400psi. Cool down N2 unit to pump off plug. 17:00 17:30 0.50 AF þMPRUI\ PUMP N2 Pump off plug with 1600psi. 17:30 18:00 0.50 AF þMPRUI\ SETREL PKR- Reciprocate pipe and set Weatherford packer with good indications. Drop ball and chase with N2 to release from packer. Printed: 10/14/2004 2:28:16 PM MARATHON OIL COMPANY Page 2 of 2 Daily Maintenance/Repair Report Increase Production WELL NAME [KB IGL 124 HR PROGITMD lTVD lDFso 1 DOLO IRPT# I DATE KENAI DEEP UNIT 2 14.6 66.00 5 30-Sep-2004 OPERATIONS SUMMARY FROM TO HRS FROM TO SUB PHASE OP SUBOP TRBL DESCRIPTION 17:30 18:00 0.50 AF þMPRUI\ SETREL PKR- Ball would not seat with N2. Pump 7bbl fluid and pressure up to 3800psi to disconnect from packer. 18:00 18:30 0.50 AF þMPRUI\ R,UNPUL COIL POOH with CT and MHA allowing N2 to vent to atmosphere via gas buster. 18:30 20:00 1.50 AF (:MPRUN RURD COIL Rig back CT equipment. Secure well for night. Will RD in AM. PERSONNEL DATA POB @ 06:00: COMPANY I SERVICE I NO. I HOURS II COMPANY T SERVICE I NO. I HOURS Marathon I Supervision I 1 I 8.00 II Pollard Wireline I Slickline I 31 33.00 . ....., LAST BOP TEST: LAST CASING TEST: NEXT BOP TEST: SIZE ID I SHOE TEST I MAX SICP I MD I TVD I WT I GRADE I BURST Printed: 10/14/2004 2:28:16 PM ~ KDU2 Pad 41-7, Kenai Gas Field Proposed Hangoff WBD API: 50-133-20121 AOGCC: RT-MSL RT-GL 405' FNL, 4381' FWL Sec. 7, T4N, R11W, S.M. Lift threads: ??? Tree cap: 4-3/4" Otis (on dual tree) :z: :z: J Tubina Strina - 3-1/2", 9.2#, N-80, Butt Mod Camco sidepocket injection mandrel @ 984' - injection valve installed 11/24/95 Baker CMO Sliding Sleeve @ 7668' ID=2.813" (closed 11/21/95) Baker K-Anchor @ 7681' Baker SAB Packer @ 7683' X-nipple @ 7734' ID = 2.813" XN-nipple @ 7807' ID = 2.750" Wireline Re-entry Guide @ 7809' =- :=!II ::J =- ::a ::J =- =- Ie: Ie: Ie -= -= Ie Ie: Ie: ActiveTvonek Perfs (2-1/2" HC, 6spf) 72-8: 7911'-7951' (3/18/96) 73-1: 7973'-7992' (3/18/96) 75-8: 8220'-8262' (11/29/95) Isolated Perfs 5119'-5120' (sqz'd 11/95) 5128'-5138' (sqz'd 11/95) 5190'-5170' (sqz'd 11/95) 5235'-5265' (sqz'd 11/95) 8245'-8255' (sqz'd 11/95) 9510'-9522' (8/13/68) 9558',9588' (8/13/68) 9854'-9874' (sqz'd 8/4/74) 9884'-9910' (sqz'd 8/4/74) 9919'-9920' (sqz'd 8/4/74) 10006'-007' (7/27/74?) 10028'-036' (8/13/68) 10080',092' (8/13/68) 120", Drivepipe @ 53' 13-3/8",54.5#, J-55, STC csg @ 1317' Cmt w/ 650 sks of class "G" -. 9-5/8",40#, N-80 "seal-lock" csg @ 6027' Cmt w/ 700 sks of class "G" through shoe & w/300 sks thru DV tool @1918' Top of 7" TIW Hanger @ 5821' Coil Tubina Velocitv Strina 1.75" OD, 0.125" WT coil tubing, Hung from Weatherford PCH packer @ -300' Minimum ID = 1.300" Landing nipple at end of coil @ 7,975' no-go ID = 1.265" Fill tagged @ 839€)' WLM 7.'13.'913 84iW WlM 7.'28/99 8200' WlM á!7.'93 89713' WLM 5.'19.'04 8268' WLM 8/9/04 Cmt Retainer @ 9325' (11//8/95) Baker Packer @ 9500' (8/18/74) Junk Retainer @ 9744' (8/9/74) Cmt Retainer @ 9750' (8/3/74) Cmt Retainer @ 9950' (8/3/74) Junk Retainer @ 10,436' (8/1/74) 7",29#, N-80, BTC liner 5821'-10,522' Cmt w/1 000 sks of class "G" Well Name & Number: KDU2 Lease I Pad 41-7, Kenai Gas Field County or Parish: Kenai Peninsula Borough I State/Provo Alaska Country: T Perforations: (MD) Tyonek (TVD) I Angle/Perfs I Angle @KOP and Depth I KOP TVD I Date Completed: I RKB: I Prepared By: DMT Last Revision Date: I ~ ~ @1Ffïi\lFrErñìmJre !K\ ~ rR. A \ ~~ ~( Æ\ @ U 1J:ü U Lb If L'U L~¿~ ~~ uulFù AI/ASIiA. OIL AlQ) GAS i CONSERVATION COMMISSION! / ¡ ! ! j / FRANK H. MURKOWSKI, GOVERNOR 333 W. P" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 September 3, 2004 \ ...,-0L\-0/ Denise Titus Marathon Oil Company P.O. Box 196168 Anchorage, Alaska 99519-6168 Re: Beluga KDU #2 Sundry: 304-338 Dear Ms. Titus: 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 rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Enclosure ~ ~ ¿ M:."1 Marathon MARATHON Oil Company Alaska Business Unit Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 August 31 , 2004 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W ih Ave Anchorage, Alaska 99501 Reference: KDU 2 Dear Mr. Aubert: Enclosed is the 10-403 Application for Sundry Approvals for Marathon well KDU 2. The proposed work is to install a 1-3/4" coiled tubing lift string in the existing 3-1/2" tubing. This work will be completed to combat erratic production and the continued need to blow the well down due to loading. Work is expected to begin September 10th. I have also enclosed a procedure and a well bore diagram for your review. If you have questions or need any additional information, I can be reached at 907-283-1333 or bye-mail at DMTitus@MarathonOil.com. Sin~reIY, ,ÆL -~ Denise M. Titus Production Engineer Enclosures RECEIVED SEP - 2. 2004 Allska Oil & Gas Cons. Commission Anchorage ORIGINAL 1. Type of Request: Abandon U Suspend 0 Operational shutdown U Perforate 0 AI WRiv1j~Jdán~lar Di~~~ as a as ons. 0 Ii Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension A h Other .¡ Change approved program 0 Pull Tubing 0 Perforate New Pool 0 nc or~e / Re-enter Suspended Well 0 Install -string 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Marathon Oil Company Development 0 / Exploratory 0 ~ /(;,g- o4Q W6A- 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 196168, Anchorage, AK 99519-6168 50-133-20121 ,./ 7. KB Elevation (ft): 9. Well Name and Number: 107' KB KDU2 / 8. Property Designation: 10. Field/Pools(s): Kenai Unit BelugalTyonek Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10522 9885 9325 8689 Casing Length Size MD TVD Burst Collapse Structural Conductor 58' 20" 58' 58' Not Cemented Not Cemented Surface 1317' 13-3/8" 1317' 1291' 2730 1130 Intermediate 6026' 9-5/8" 6026' 5418' 5750 3090 Production Liner 4701' 7" 10522' 9898' 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8222-62, 7973-92, 7911-51 7597-639, 7350-92, 7288-328 3-1/2" N-80 7809 Packers and SSSV Type: Baker SAB Packer Packers and SSSV MD (ft): 7683 12. Attachments: Description Summary of Proposal U 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 14. Estimated Date for / 15. Well Status after proposed work: Commencing Operations: 9/10/2004 Oil 0 Gas 0 ~IUgged 0 Abandoned 0 16. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 17. I hereby certify that t .e foregoing is true and correct to the best of my knowledge. Contact 907/283-1333 Printed Name De ise M. Tituryj Title Production Engineer - .. Signature II ~ 1 UVII Phone (QO1) Z~3-13'<;3 Date 8/31/2004 , COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3ó4 - 3 3ð-' Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: S"""q","~- 404 R8DMS 8FL SEP 08 700L OR\G\NAL BY ORDER OF 'l/.g/ðlf /' Approved by: T ~ ~W COMMISSIONER THE COMMISSION Date: Form 1 0-403 ~d bO03 INSTRUCTIONS ON REVERSE SU/mit lDuPlicate ~ STATE OF ALASKA ~ ALA~r..A OIL AND GAS CONSERVATION COMMI~SION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 \MC:l/, '1/1-fLOC7+ ~/3/~ DO RECEIVED SEP -'22004 iol ~ ~ ~~ \ ~"'THO.J Marathon. Oil Company Alaska Region KDU2 Kenai Gas Field, Pad 41-7 / Veiocity String JHIangoff Procedure History: KDU 2 displays erratic flow consistent with well loading. The \vell is often turned to the 10'1'/ pressure system leJ unload 'waTer and tempOI'arily i:mprove flo\ì;¡rates. Objecf¡ive: Install 8 velocity string in KDU :< to aHmv stable production rates and pressures and to facilitate unloading. Procedure: 1. MIRU 1%" coil tubing unit onto tree flange. Reel should consist of at least 8300' of 1 %", 0. .125" wall thickness, u~ed coil tubing :vith externally pressure teste~_~d on' ~11readed connector. Conduct prejob safety meetIng. NU BOPE, and test to 25f/3~O{ypsl. Purge / coil tubing reel with nitrogen and break stack. '--:// 2. MU hang offBHA to threaded CT connector including, 10' straight bar, BST coil tubing T-1 Profile (1.032" ill) and pump-out plug onto the end of the coil tubing. NU injector head and completed body test pumping fluid through kill line to 250/1 OOOpsi. " oJ. Rill with coil tubing to 8200' KB. (Note: Will be unáble to circulate with the pump-out plug installed onto the end of the coil tubing.) Attempt to flow well up the coil tubing annulus while RIH. Monitor production via tubing annulus until satisfied that the well will produce independently. 4. Pick up pipe to 7675'. Set sìips on 1%" coil tubing and close the pipe rams. Bleed ofÍ trapped pressure above the BOPE, and monitor pressure gauges to confinn that the slips /' and the pipe rams are holding as designed. Break the lubricator and walk injector head up the pipe per BJ procedure, 5, Install safety clamp and C-plate on coil tubing. Cut a weephole in the pipe to ensure no / internal pressure. If pressure remains zero, cut the 1 %" coil tubing, and ND injector head with the cut tubing. 6. Install vVeatherÎord PDH coil tubing packer onto the coil tubing. Confinn required ball size for the hydraulic release. Install WeatherÎord mechanical setting tool, and l'1ydraulic releasing tool onto the coil tubing stub in the injector head. Pull test to 25,000 lbs. ~ ~ 7. PU injector head with mechanical setting tool and hydraulic release. Engage the PDH packer with the mechanical setting tool. Pull te'st connection, When it is confirmed that the setting tool is engaged onto the packer, remove the safety clamp and walk the injector head down the pipe to seal the lubricator. Equalize pressure across the pipe rams, then open the pipe rams. PU to coil tubing running weight, then open the slips. Keep the PDH packer up in the lubricator for the time being. 8. Pressure up on the coil tubing with nitrogen to blowout the pump-out plug. Once the pump-out plug is removed, jet well with nitrogen as needed to stabilize flow to the open ./0/ top tank. Do not continue the procedure until confident that the well is unloaded and capable of independent flow. g. Shut-in nevI at the flow cross. RIE with the PDH packer to :1::300' below the top ofthe tubing hanger. Reciprocaæ the coil tubing around the :1::20' mark per Weatherford procedure to set the mechanical packer. Apply coil tubing weight to verify that the packer is set. 10. Place a jig" ball (verify size) into the coil tubing string, and displace with 6% KC1 to the hydraulic releasing tool. Pressure up to release from the PDH packer. PU to verify that the coil is released from the PDH packer. Set back down on the PDH packer one more time to confirm that it is still in place, 11. PU above the swab valve with the coil tubing, and close the swab to isolate the coil. Displace reel with nitrogen as needed. Once the CT is blown down, break injector head and set aside. Install night cap on BOPs and blow N2 off well to tank Until methane is detected from gas detector. Confirm that the well is producing as expected up the velocity string before allowing coil tubing to rig do~m. / 12. RDMO coil tubing. Produce well KDU 2 to the low pressure system. ,~ .~ ~ KDU2 Pad 41-7, Kenai Gas Field Proposed Hangoff WBD API: 50-133-20121 AOGCC: RT-MSL RT-GL 405'FNL,4381'FVVL Sec. 7, T4N, R11W, S.M. Lift threads: ??? Tree cap: 4-3/4" Otis (on dual tree) z: z: _T Tubina Strina - 3-1/2", 9.2#, N-80, Butt Mod Camco side pocket injection mandrel @ 984' - injection valve installed 11/24/95 Baker CMO Sliding Sleeve @ 7668' ID=2.813" (closed 11/21/95) Baker K-Anchor @ 7681' Baker SAB Packer @ 7683' X-nipple @ 7734' ID = 2.813" XN-nipple @ 7807' ID = 2.750" Wireline Re-entry Guide @ 7809' =- =- :::J =- """" :::J """" """" ActiveTvonek Perfs {2-1/2" HC, 6spf) 72-8: 7911'-7951' (3/18/96) 73-1: 7973'-7992' (3/18/96) 75-8: 8220'-8262' (11/29/95) Isolated Perfs 5119'-5120' (sqz'd 11/95) 5128'-5138' (sqz'd 11/95) 5190'-5170' (sqz'd 11/95) 5235'-5265' (sqz'd 11/95) 8245'-8255' (sqz'd 11/95) 9510'-9522' (8/13/68) 9558'-9588' (8/13/68) 9854'-9874' (sqz'd 8/4/74) 9884'-9910' (sqz'd 8/4/74) 9919'-9920' (sqz'd 8/4/74) 10006'-007' (7/27/74?) 10028'-036' (8/13/68) 10080'-092' (8113/68) 120", Drivepipe @ 53' 13-3/8",54.5#, J-55, STC csg @ 1317' Cmt w/ 650 sks of class "G" - 9-5/8",40#, N-80 "seal-lock" csg @ 6027' Cmt w/ 700 sks of class "G" through shoe & w/300 sks thru DV tool @1918' Top of 7" TIW Hanger @ 5821' Coil Tubina Velocity Strina 1.75" OD, 0.125" WT coil tubing, Hung from Weatherford PCH packer @ -300' Minimum ID = 1.300" Landing nipple at end of coil @ xxxx' no-go ID = 1.265" II::: II::: I:: II::: II::: I:: II::: II::: Fill tagged @ 8J9ê' WLM 7!1J!9ê 8484' WLM 7/28!99 / 8299' 'NLM 51710J 8Q7ê' WLM 5!19/04 8268' WLM 8/9/04 Cmt Retainer @ 9325' (11//8/95) Baker Packer @ 9500' (8/18/74) Junk Retainer @ 9744' (8/9/74) Cmt Retainer @ 9750' (8/3/74) Cmt Retainer @ 9950' (8/3/74) Junk Retainer @ 10,436' (8/1174) 7",29#, N-80, BTC liner 5821'-10,522' Cmt w/1 000 sks of class "G" Well Name & Number: KDU 2 Lease I Pad 41-7, Kenai Gas Field County or Parish: Kenai Peninsula Borough I State/Provo Alaska Country: -I. Perforations: (MD) Tyonek (TVD) I Angle/Perfs I Angle @KOP and Depth I KOP TVD I Date Completed: I RKB: I Prepared By: DMT Last Revision Date: I ( \ ( MEMO TO EACH WELL FILE LISTED BELOW Date January 7, 2004 Two previously undefined intervals, the D 1 sand of the Tyonek Formation and the Beluga Formation in the Kenai Unit of the Kenai Gas Field, have been combined into a single defined pool the Kenai, Beluga/Tyonek Gas Pool, field & pool code number 448571. This change was effective in January 2004. Production from these two intervals had previously been reported to production codes 448569 Kenai, Beluga Undefined Gas and 448570 Kenai, Tyonek Gas. These codes have been deleted from some of the wells listed below. The wells listed below have had their production records modified reflecting this change. 184-109 181-153 195-055 174-050 178-055 1 77-029 185-181 202-043 179-029 184-108 199-024 200-188 200-179 $CA"~NEtïJ) JAN 2 0 2004 KBU 23X -06 KBU 31-07 KBU 31-07RD KU 14-06RD KDU5 KBU 13-08 KBU 33-07 KTU 32-07H KBU 41-07 KTU 13-05 KBU 33-06 KBU 24-06 KBU 44-06 200-023 168-049 184-108 199-024 195-054 203-066 199-073 195-054 169-012 179-030 199-025 202-025 KTU 32-07 KDU2 KTU 13-05 KBU 33-06 KTU 43-06XRD KBU 43-07X KTU 24-06H KBU 43-06XRD KDU4 KBU 43-06X KBU 42-07 KBU 41-07X ( l Alaska i\ .lIon Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 May 20, 1996 Mr. Jack Hartz Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Hartz: Please find attached a completed Gas Well Open Flow Potential Test Report for Kenai Gas Field Well KDU 2. The test was completed on April 23, 1996. Marathon respectively requests this information be kept CONFIDENTIAL for a period of two years for strategic planning purposes. Sincerely yours, ~9~ Michael J. Stover Advanced Reservoir Engineer MJS/kz:ENG\AOGCC3.L TR Attachment RECE1\/FD MA V t 2.. ~O".~ "'aska Oft & (3as Gf1n~ ¡;utl~)j~~ AoohtU~Ð SCANNED OCT 2 ? 2003 A subsidiary of USX Corporation Environmentally aware for the long run. ( { R ECE IVED STATE OF ALASKA MAY 2 2 199& ALASKA OIL AND GAS CONSERVATION COMMISSION GAS WELL OPEN FLOW POTENTIAL TEST REI'~iI & Gas Cons. Commission Anchorage 1 a. TEST: INITIAL § 1b. TYPE TEST STABLlLlZED D NON STABILIZED § ANNUAL MULTIPOINT ~ CONSTANT TIME SPECIAL OTHER ISOCHRONAL 2. Name of Operator 7. Permit No. Marathon Oil Company 68-49 3. Address 8. API Number 3201 C Street, Ste. 800, Anchorage, Alaska 99503-3934 50- 133-20121 4. Location of Well 9. Unit or Lease Name At surface Kenai Unit 405' FNL & 4381' FWL, Section 7: T4N, R11W, S.M. 10. Well Number At Productive Interval Kenai Deep Unit #2 511'FNL,1726'FWL,Sec.8,T4N,R11W,S.M. 11. Field and Pool Kenai Gas Field 5. Elevation in feet (KB, DF etc.) 6. Lease Designation and Serial No. 107' KB Anchorage 028142 12. Completion Date 13. Total Depth 14. Plugback TD. 15. Type Completion (Describe) 11/26/95 10,522 9325 Single Tbg. String / Cased Hole 16. Csg. Size Weight per foot, lb. I.D. in inches Set at ft. Perforations: From To 7" Liner 29 6.184 10,522 7911' 7951' 17. Tbg. Size Weight per foot, lb. I.D. in inches Set at ft. 7973' 7992' 31/2" 9.2 2.992 7809 8222' 8262'- 18. Packer set at ft. 19. GOR crIbb!. 20. API Liquid Hydrocarbons 21. Specific Gravity Flowing fluid (G) 7683 --- --- 0.5597 22. Producing thru: Reservoir Temp. of. Mean Annual Temp. of. Barometric Pressure (Pa), psi a Tbg. [8] csg.D 138 33 14.73 23. Length of flow channel (L) Vertical Depth (H) Ga. % CO2 %N2 %H2S Prover Meter run Taps 7809' 7174' 0.12 0.422 0 x 24. Flow Data Tubing Data Casing Data Choke Prover Orifice Line Size X Size Pressure Ditf. Temp. Pressure Temp. Pressure Temp. Duration of Flow No. (in.) (in.) psig hw of. psig of. psig of. Hr. 1. 3" X 2" 270.4 5.2 78 2100 61 -- -- 2.00 2. 3" X 2" 270.4 5.2 80 1940 61 -- -- 2.00 3. 3" X 2" 270.4 5.2 84 1750 61 -- -- 2.00 4. 3" X 2" 270.4 5.2 84 1550 61 -- -- 2.00 - ,-. 5. X Basic Coefficient ~ (24-Hour) hwPm Pressure Flow Temp. Factor Gravity Factor Super Compo Factor Rate of Flow No. Fb or Fp Pm Ft Fg Fpv Q, Mcfd 1. 68.3 37.5 285.1 0.983129 1.336664 1.018192 2,560 2. 77.3 37.5 285.1 0.981307 1.336664 1.01796 2,900 3. 93.3 37.5 285.1 0.977692 1.336664 1.017506 3,500 4. 104.0 37.5 285.1 0.977692 1.336664 1.017506 3,900 5. Temperature for Separator Gas for Flowing Fluid No. Pr T Tr Z Gg G 1. 0.418158 537.6 1.582 0.964585 0.5597 2. 0.418158 539.6 1.588 0.965025 3. 0.418158 543.6 1.600 0.965886 þritical Pressure 681.8 4. 0.418158 543.6 1.600 0.965886 þritical Temperature 340.1 5. Form 10-421 Rev. 7-1-80 kz\AOGCCGAS.xLS CONTINUED ON REVERSE SIDE Submit in duplicate (' Ii Pc 2,500 Pc2 6,250,000 Pf PF No. Pt pt2 Pc2 - pt2 Pw P~ Pc2 - P~ Ps PS2 PF - PS2 1. 2,100 4,410,000 1,840,000 - - - 2. 1,940 3,763,600 2,486,400 - - - 3. 1,750 3,062,500 3,187,500 - - - 4. 1,550 2,402,500 3,847,500 - -- -- 5. 25. AOF (Mcfd) 5,399 n 0.6586 Remarks: Surface data only was collected during test. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~S.¡".,. -"'" Title Advanced Reservoir Engineer Date 5/20/96 AOF DEFINITIONS OF SYMBOLS Fb Fp Fg Fpv Ft G Gg GOR hw H L n Pa Pc Pf Pm Pr Ps pt Pw Q Tr T Z Form 10-421 Rev. 7-1-80 kz\AOGCCGAS.xLS Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia. Basic orifice factor Mcfd/ ..J hw/Pm Basic critical flow prover or positive choke factor Mcfd/psia Specific gravity factor, dimensionless Super compressibility factor = ..J 1/Z dimensionless Flowing temperature factor, dimensionless Specific gravity of flowing fluid (air = 1.00), dimensionless Specific Gravity of separator gas (air=1.00), dimensionless Gas-oil ratio, cu. ft. of gas (14.65 psi a and 60° F.) per barrel oil (60° F) Meter differential pressure, inches of water Vertical depth corresponding to L, feet (TVD) Length of flow channel, feet (MD) Exponent (slope) of back-pressure equiation, dimensionless Field barometric pressure, psia Shut-in wellhead pressure, psi a Shut-in pressure at vertical depth H, psia Static presssure at point of gas measurement, psia Reduced pressure, dimensionless Flowing pressure at vertical depth H, psia Flowing wellhead pressure, psi a Static column wellhead pressure corresponding to Pt, psi a Rate of flow, Mcfd (14.65 psia and 60°F.) Reduced temperature, dimensionless Absolute temperature, degrees Rankin Compressibility factor, dimensionless R'ECEIVED MAY 2 2 1996 Alaska OJI & GG1~~ Cons GOH~ Aacbarqs Recommended procedures for tests and calculations may be found in the MANUAL OF BACK-PRESSURE TESTING OF GAS WELLS, Interstate Oil Compact Commission, Oklahoma City, Oklahoma CONTINUED ON REVERSE SIDE Submit in duplicate KDU#2 - 72-8, 73-1 & 75-8 (4/23/96) 4-Point Test Results 0 Pth Pth (5.1.) (mscfd) (psia) (psia) 2,560 2,100 2,500 2,900 1,950 2,500 3,500 1,750 2,500 3,900 1,550 2,500 m= 1.5183 (psiA2/mcf) 11m = n = 0.6586 (mcf/psiA 2) AOF = 5,399 mscfpd ... 10,000,000 - N ( ~ .tñ Q. - .. Ñ ( .c ö:. 1,000,000 N ( - . - . U) - .c ö:. - ,f \ Pres. Drop (psia) 400 550 750 950 Actual (0) 2,560 2,900 3,500 3,900 Actual (PrA 2-Pwf A 2) 1,840,000 2,447,500 3,187,500 3,847,500 Ave. Coeff. C Regression 'C' KDU 2 - U. Tyonek 04/23/96 ~' Surface Results Calc. C 0.1915 0.1797 0.1823 0.1794 0.18048 0.18047 Regression (0) 2,41 3 2,912 3,465 3,923 ~ ~ ....-- --. 100,000 1000 0 (mscfd) ACTUAL 2,560 2,900 3,500 3,900 PREDICTION 4,024 4,468 4,814 5,175 5,400 Q, (mscfpd) I . 4-Pt. Test -Regression I Pth Pth (5.1.) Pres. Drop % (psia) (psia) (psi a) Drawdown --- 2, 1 00 2,500 400 16.00 1,950 2,500 550 22.00 1,750 2,500 750 30.00 1,550 2,500 950 38.00 1,500 2,500 1,000 40.00 1,250 2,500 1,250 50.00 1 ,000 2,500 1,500 60.00 625 2,500 1,875 75.00 0 2,500 2,500 100.00 h:\excel\kenai\belugaKDU 24PT1 .XLS 10000 RfrF"Jf:O ~ 'I V i"') ') ï (' :' ;: 'ahlll!!"'-',." I,)".~' ':.:',-1',' (;f.'I,., \i:,¡:,¡\I.:J::iS-On ",-",,'\'ii, 'i' '\,1' " " .,," Äln.,hìJt¡¡g6 ~ \ i' AlaskJ, Jgion Domestic Production Ma rathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 April 4, 1996 Joan Miller Alaska oil & Gas Conservation commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Dear Joan: Please find attached the following "Report of Sundry Well Operations" for Kenai Gas Field Wells: KDU 2 - Recompletion KDU 4rd - Recompletion Please find attached the following "Well Completion or Recompletion Report and Log" for Kenai Gas Field Wells: KBU 31-7 - Abandoned KBU 31-7rd - sidetracked KTU 43-6X - Abandoned KTU 43-6Xrd - Sidetracked A "Report on Sundry Well Operations" for KBU 41-7 (approval 'number 95-089) will be submitted following completion of the perforating and fracturing work. Should you have any questions regarding any report, please contact Mike Olson at 907-564-6315. Sincerely, , ) ...,...".... ---'~ \ ,/" C ) , I, ,.~ ' ' ~<),-.----_..._,--_. ~:::::_",........ ,r-""\ T. J . (Ko~acevich operatiJns Superintendent .. , 'I ,'."¡j",~'~,,,.,~:~1) w,\>\,.'"" i""""'" '{', ~1"""" ii "I. ,:¡' Iii ~ ,¡;¡ ~ ':" [ç",." '\""él >I""".., i.\ OJ, iJt¡""", """'" p,PR 0 4- 19'96 Attachments ",~\:¡¿;~)i::~i\ ,O::¡ 8,. "" ,r', . ...'..¡e',",¡(,,"¡¡I'I¡t,~ ¡"'V";':, !( X"'i¡: ""'\,,'~!Wi~ ',.p',-",~.g"."";.¡,,,,"'¡'¡' ,f;, "'I,"h;>'t,""H,ß~ Mol h~~ P"),;(!.;<i;,i'¡' cc: CEF A subsidiary of USX Corporation Environmentally aware for the long run. O:\EXCEL\SUNDRY,XLS ( STATE OF ALASKA It ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS . . 1. Operations performed: Operation Shutdown - Pull Tubing ~ 2. Name of Operator Marathon Oil Company 3. Address P.O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 405' FNL, 4381' FWL, Sec 7, T4N, R11W, S.M. At top of Productive Interval 511' FNL, 1726' FWL, Sec 8, T4N, R11W, S.M. At Effective Depth At Total Depth 541' FNL, 1804' FWL, Sec 8, T4N, R11W, S.M. 12. Present Well Condition Summary Total Depth: measured true vertical Effective Depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length 58' 1317' 6026' 4701' 8222-8262',7973-7992',7911-7951' Perforation Depth: measured 7586-7626', 7337-7356', 7275-7315' true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 13. Stimulation or Cement Squeeze Summary Intervals Treated (measured) 8222-8262' Treatment Description Including Volumes Used and Final Pressure Frac'd w/13,OOO# of 16/20 Carbolite, 195 bbls, 3800-5100 psig 1 0522' feet 9885' feet 9325' feet 8689' feet Size 20" 13-3/8" 9-5/8" 7" Stimulate X Alter Casing - 5. Type of Well: Development ~ Exploratory - Stratigraphic - Service Plugging ~ Perforate X Repair Well - Other X 6. Datum Elevation (DF or KB) 107' KB 7. Unit or Property Name Kenai Deep Unit 8. Well Number KDU #2 9. Permit Num 95-091 10. API Number 50-- 133-20121 11. Field/Pool Kenai Gas Field feet ORIGINAL Plugs (measured) Junk (measured) Cemented Measured Depth True Vertical Depth Driven 58' 58' 650 SX 1317' 1291' 1000 SX 6026' 5418' 1000 SX 1 0522' 9898' 3-1/2",9.2#, N-80, 7809' ,," [""") " ., '\, '~"~,,, ,...,.,.,~.'I """¡ih~,',' r~~. L... \...ð1' f_.. a ~J li.IJ>",.. t", 7683' Baker SAB 84-42 X 32 packer ------ Signed J þ"PR 0 4 1996 '", . ~ ,..r."'1":Î(~...J^!m "'I :¡) r:,.;'.~. I r ¡,~" A.Ji¡hh\ i..~~t~,¡!~ AIìChIJra~~a Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Subsequent to Operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X Oil Gas X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 14. Prior to Well Operation Form 10-404 Rev, 06/15/88 3264 / 3731 270 0 1460 0 16. Status of Well Classification as: ... Suspended - Service Title Ops. 5 c..( P,. ' '1,(, Submit in Duplicate ~ ." DATE:. . RPT 10/27/95 10/28/95 10/29/95 10/30/95 10/31/95 11/01/95 11/02/95 11/03/95 11/04/95 11/05/95 :. . :'. '. DEPTH 1 2 3 4 5049 5 5114 6 5603 7 5603 8 5603 9 5603 10 9347 ( ( OPERATION SUMMARY REPORT . . WELL: KDU-2 W/O . . . MUD" WT . . . 0 9.500 0 9.500 0 9.500 10.000 10.050 10.200 10.500 10.900 12.000 12.600 . . .. .. . . . .. . . . DAILY OPERATIONS 'SUMMARY :' . . . . . .. . . ACCEPTED RIG FROM MOB AT 1200 HRS 10-26-95. MIXED 400 BBLS OF 9.5 PPG MUD.KILLED WELL. N/D TREE. N/U BOPE. N/U BOPE. SET TWO WAY CHECKS IN HANGER. TESTED BOPE. PULLED TWO WAY CHECKS. DROPPED ONE ON HANGER. FISHED OUT TWO WAY CHECK. SCREWED INTO BUT COULD NOT PULL SHORT STRING. ALLOWED tUBING AND ANNULUS TO EQUALIZE. MONITORED WELL. REPAIR RIG. RIH WITH JET CUTTER. CUT SHORT STRING AT 50491 WLM. PooH.CBU. PULLED AND L/D 2 7/8" TUBING. RIH WITH CHEMICAL CUTTER. CUT LONG STRING AT 51231. POOH. CBU. FINISHED CIRCULATING. ROTATED LONG STRING TO RELEASE PACKER. PACKER WOULD NOT RELEASE. RAN FREE POINT. RIH WITH STRING SHOT AND BACKED OFF TUBING AT 50741 WLM. R/D WIRELINE. PULLED AND L/D 2 7/8 TUBING. M/U FISHING ASSEMBLY. RIH P/U 3 1/2" DRILL PIPE. RIH P/U DRILL PIPE. MILLED OVER AND LATCHED FISH AT 50481. JARRED FISH FREE. CBU. POOH. RECOVERED DUAL PACKER, REMAINDER OF SHORT STRING AND CUT PIECE ON LONG STRING BELOW PACKER. L/D FISH. RIH AND LATCH FISH AT 51141. CHASED TO 51621. CBU. POOH. POOH AND L/D 48.51 OF FISH. RIH WITH FISHING TOOLS. COULD NOT LATCH FISH AT 51621. POOH. REDRESSED OVERSHOT. RIH. MILLED OVER AND LATCHED FISH. PULLED FREE. CBU. POOH. L/D FISH. RECOVERED 441.51. TOF 56031. RIH WITH 8.5" MILL FOR GUAGE RUN. RIH WITH MILL. WORKED THROUGH TIGHT SPOT AT 52291, TAGGED TOP OF FISH AT 56031. CBU. POOH. M/U OVERSHOT AND RIH. ATTEMPTED TO WORK OVER TOP OF FISH W/O SUCCESS. CBU. POOH, HAD 11 TUBING IN OVERSHOT. M/U MILL AND EXTENSION SUBS AND RIH. MILLED TIGHT SPOT IN CASING AT 52291. WASHED OVER TOP OF FISH TO PACKER AT 56121. CBU. POOH WITH MILL. M/U OVERSHOT AND START RIH. REPAIRED RIG DRAWWORKS DRIVE CHAIN. RIH. LATCHED FISH. JARRED ON SAME. GAS BUBBLING UP. CIRCULATE ON CHOKE. OPEN WELL AND CBU, GAS WOULD NOT DROP OUT. RAISE MUD WT FROM 10.5 PPG TO 10.9PPG AND CIRCULATED AROUND. R/U W/L. RIH WITH 2 1/8" SPUD BIT. COULDN'T GET INSIDE FISH, POOH. JARRED ON FISH. R/U W/L. RIH WITH 1 11/16" SPUD BIT TO 94601, POOH. CIRCULATED AND RAISED MUD WT FROM 10.9 PPG TO 12.0 PPG. R/U W/L. RIH WITH 1 1/8" SEVERING TOOL, FIRED SAME AT 93471 WLM. POOH, R/D WILD CIRCULATED OUT GAS, RAISED MUD WT TO 12.3PPG. CIRCULATED 12.3 PPG MUD AROUND, 300 UNITS OF GAS. CIRCULATED AND RAISED MUD WT TO 12.6PPG. POOH SLOWLY 19 STANDS. HOLE STARTED TAKING MUD. FILLED HOLE WITH 76 BBLS MUD. MONITER WELL. LOSING 60 BPH. FILL HOLE WITH 22 BBLS MUD, WELL STARTED FLOWING. SHUT IN WELL FOR 30 MIN WITH NO PRESSURE. OPEN WELL, FILL HOLE WITH 8 BBLS MUD. WELL FLOWED. SHUT IN WELL. BUILD MUD VOLUME. CIRCULATED LCM PILL * { (" OPERATION SUMMARY REPORT WELL: KDU-2 WIO . DATE RPT DEPTH MUD WT. DAILY OPERATIONS SUMMARY AROUND ON CHOKE. MONITER WELL. POOH WITH FISH. 11/06/95 11 9347 12.600 LID BHA. SHUCK OVERSHOT. POOH LID 2 1/8" TUBING. RECOVERED 120 JTS. TOTAL LENGTH OF 37321. PIU 611 BIT AND 7" CASING SCRAPER. RIH WITH DP. PIU 9 5/8" CASING SCRAPER. RIH PIU DP. HOLE STARTED TAKING MUD ONCE INSIDE 7" LINER. TAGGED FISH 93501. MONITER WELL, TAKING 60BBL MUD/HR. MIX AND SPOT 60 LCM PILL. BUILD MUD VOLUME. 11/07/95 12 9347 12.600 FINISH BUILDING MUD VOLUME. OPEN WELL AND FILL WITH 34 BBLS. HOLE STAYING FULL. POOH TO 51001, FLUID LOSS INCRASED TO 60 BPH. RIH 10 STANDS TO 57621. SPOTTED 60 BBL LCM PILL. BUILD MUD VOLUME. FILLED ANNULUS WITH 94 BBLS. HOLE TAKING 108 BPH. POOH 10 STD TO 51151. SPOTTED 55 BBL LCM PILL. SHUT IN WELL, BUILD MUD VOLUME. 11/08/95 13 9325 12.500 BUILD MUD VOLUME. OPEN WELL AND FILL WITH 120 BBLS MUD. HOLE TAKEING 180 BBLS/HR. SHUT IN WELL. BUILD MUD VOLUME AND FILL RESERVE PIT WI WATER. OPEN WELL AND FILL WITH 94 BBLS WATER. HOLE TAKING 15 BBLS/HR POOH. MIU CEMENT RETAINER AND RIH. SET RETAINER AT 93251. POOH. LID 7" SETTING TOOL. MIU 9 5/8" CEMENT RETAINER AND SETTING TOOL. START RIH. 11/09/95 14 9325 9.900 RIH AND SET 9-5/8" RETAINER AT 53051. POOH. RIH WITH DIVERTER TOOL TO 53051. ATEMPT TO CIRCULATE WITH 11.6 PPG MUD AND THEN ATTEMPTED 10.5 PPG MUD. HOLE TAKING FLUID. FILLED HOLE WITH WATER. POOH. RIH AND SET 9-5/8" RETAINER AT 46801. STARTED CIRCULATING WITH 9.5 PPG MUD. 11/10/95 15 9325 9.900 CONDITION MUD. TEST CASING TO 2000 PSI. SQUEEZE 310 SACKS OF CEMENT INTO STERLING PERFORATIONS. FINAL SQUEEZE PRESSURE WAS 400 PSI. SET RETRIEVABLE BRIDGE PLUG AT 10001. NIPPLE DOWN 3000 PSI TUBING HEAD. NIPPLE UP 5000 PSI TUBING HEAD. STARTED TESTING BOPE. 11/11/95 16 9325 9.900 FINISHED TESTING BOPE. RIH. DRILL RETAINER AT 46801. DRILL CEMENT FROM 48701 TO 51501. STARTED CIRCULATING OUT. 11/12/95 17 9325 10.000 TESTED UPPER SET OF STERLING PERFS. PUMPED IN AT 750 PSI. DRILLED CEMENT FROM 5150lTO 51701. FELL OUT OF CEMENT. WASHED TO RETAINER AT 53051. CIRCULATED. TESTED ALL STERLING PERFS. PUMPED IN AT 500 PSI. POOH. RIH WITH DIVERTER TO 53051. CIRCULATED. MIXED AND PUMPED 310 SACKS OF CEMENT. SPOT BALANCED PLUG. POOH TO 40001. REVERSED OUT. SQUEEZED 31 BBLS OF CEMENT INTO STERLING PERFS. WOC. 11/13/95 18 9325 10.000 POOH WITH DIVERTER. RIH WITH 8-1/211 BIT. WASH AND REAMED FROM 40001 TO 48821. DRILLED CEMENT TO 51501. TESTED UPPER SET OF STERLING PERFORATIONS TO 1000 PSI. DRILLED CEMENT TO 52101. TESTED UPPER AND MIDDLE SET OF STERLING PERFORATIONS TO 1000 PSI. CONTINUED DRILLING CEMENT. 11/14/95 19 9325 12.500 TESTED STERLING PERFORATIONS TO 1000 PSI. RAISED MUD WEIGHT TO 12.6 PPG. TESTED WELLBORE TO 300 PSI. POOH. RIH WITH ROTARY SHOE . J ( (' OPERATION SUMMARY REPORT WELL: KDU-2 WIO . DATE RPT DEPTH MUD WT. DAILY OPERATIONS SUMMARY TAGGED UP AT 49181. STARTED WASHING. 11/15/95 20 9325 12.600 WASHED CEMENT SHEATH TO 53051. CIRCULTATED OUT. RETEST WELLBORE TO 300 PSI. MILL ON RETAINER AT 53051WITH ROTARY SHOE. TRIP FOR NEW SHOE. FINISHED MILLING OVER RETAINER AT 53051. CIRCULATED OUT. NO GAS. PUSHED RETAINER TO TOP OF 711 LINER. CIRCULATED OUT. STARTED TRIP FOR OVERSHOT. 11116/95 21 9325 12.600 POOH. PIU OVERSHOT AND RIH TO 58111. CBU. LATCHED RETAINER AT 58331. POOH. RECOVERED RETAINER. MIU 611 BIT AND RIH, PUSHED JUNK DOWN LINER TO 7580. CIRCULATED OUT OLD MUD. RIH TO 93251. CIRCULATE OUT OLD MUD AND CONDITIONED MUD. 11/17/95 22 9325 12.800 CONDITIONED MUD. TESTED CASING TO 300 PSI - OK. POOH. PIU 711 AND 9 5/811 CASING SCRAPERS AND RIH. REAMED 9 5/811 SCRAPER FROM 48181 TO 53141. CBU. RIH TO 93251. CIRCULATED AND CONDITIONED MUD. 11/18/95 23 9325 12.800 CONDITIONED MUD. TESTED CASING TO 300 PSI. POOH, LID DRILLPIPE. WORK BIT AND SCRAPER THROUGH LINER TOP, TAKING WEIGHT. CBU. REPAIRED MONKEY BOARD. POOH. MIU LINER TOP DRESSING MILL AND RIH. DRESSED OFF TOP OF LINER. CBU. POOH, LID DRILLPIPE. 11/19/95 24 9325 12.900 LID DRILLPIPE AND DRILL COLLARS. RIU AND RUN 3 1/211 PRODUCTION TUBING. MIU HANGER AND LAND SAME WITH TAIL PIPE AT 78081. RUN IN ANCHOR PINS ON HANGER. PREP TO DISPLACE TUBING WITH WATER. 11/20/95 25 9325 12.900 RIU AND DISPLACED TUBING WITH GEL PILL AND WATER. RIU SLICKLINE. RIH WITH IPXI PLUG, GOT STUCK SHEARED OFF. TOOK TWO RUNS TO RETRIEVE SAME. RIH WITH IPXI PLUG AND SET AT 78061. SET EQUALIZING PRONG IN SAME. OPENED SLIDING SLEEVE, TOOK TWO ATTEMPTS. REVERSED OUT MUD WITH WATER. 11/21/95 26 9325 8.600 REVERSE CIRCULATED WATER UNTIL CLEAN. RESVERSE CIRCULATED HOLE WITH INHIBITED 6% KCL. RIU SLICK LINE AND CLOSED SLIDING SLEEVE. TESTED ANNULUS TO 1300 PSI. NID BOPIS. NIU TREE AND TESTED SAME. RIU SLICK LINE, RIH AND RETRIEVED EQUALIZING PRONG. RIH AND LATCHED IPXI PLUG. POOH WITH SAME. 11/22/95 27 9325 FINISH POOH WITH IPXI PLUG. SET BPV. RELEASED RIG AT 0700 HRS 11-21-95 TO DEMOB. J , '" DATE 11/24/95 11/26/95 11/29/95 12/4/95 12/18/95 12/23/95- 12/24/95 1/23/96 3/7 /96 3/18/96 R?T DEE?TH ( It OPERATION SUMMARY REPORT: MUD WT. POST RIG WELL: KDU 2 ... . DAILY OE'ERATICNS SUMMARy. ... .... . ... ... ..... .. .. REPLACE DUMMY VALVE W/ CHEMICAL INJECTION VALVE @ 984'. CLEANOUT MUD FROM 8500-9000' USING CT. DISPLACE HOLE W/ 3% KCL. PU TO 7800' AND DISPLACE FLUID W/ N2. LEFT 3000 PSIG N2 PRESSURE. PERF 8222-8262' (75-8 SAND). 2000 PSIG WHP. Qi = 360 MCFPD, 0 BWPD, RIH W TANDEM ELECTRONIC GAUGES. OBTAIN FBHP AND 72 HOUR PBU. Q - 214 MCFPD, 0 BWPD, 2017 PSIG, 10.6% DO. REPLACE CHEMICAL INJECTION VALVE W/ DUMMY VALVE @ 984'. RU TREE SAVER AND FRACTURE 75-8 SAND W/ 13000# OF 16/20 CARBOLITE AND 195 BBLS FLUID (FINAL STAGE HAD 1.5% PROPNET). RD TREE SAVER AND REPLACE DUMMY VALVE W/ CHEMICAL INJECTION VALVE. RU CT AND CLEANOUT WELLBORE TO 8400'. JETTED WELL IN W/ N2 FROM 2000-4000'. WELL FLOWING 930 MSCFPD @ 2120# WHP. MU TANDEM ELECTRONIC GAUGES AND OBTAIN FBHP AND 96 HR PBU. TAG FILL @ 8517'. Q = 1042 MSCFPD, 0 BWPD, 2000 PSIA WHP, 14.8% DO. MU TANDEM ELECTRONIC GAUGES AND OBTAIN FBHP AND 96 HR PBU. TAG FILL @ 8518'. Q = 2012 MSCFPD, 0 BWPD, 1600 PSIA WHP, 28.5% DO. PERF 7373-7992' (73-1 UPPER TYONEK), 7911-7951' (72-8 UPPER TYONEK). TAG FILL @ 8499'. Q = 2142 MSCFPD, 0 BWPD, 1850 PSIG WHP. > .-- KDU2 :'--tt.I\i"'~ : ..m_._...m......m_._......m.._..m.- HANGER: 24. 9 (00: 11. 125 ID: 2 . 992) 3.~ : ...m........................_.m.......-...--...........m.__.-'-- ...-..-.-.-.--- -.... ......'-'- -..................- -.' - -- - -.. -- - -- -.. ....... J 3 "¡...-.-...--........._.....m............-....._....m._.......m_..m...-..--........- .......- ..-......-...- -...........-.-...- ..-..-.. -" --- .cO ..Lm...........-_...m......._.m.....m...- SURFACE CASING: 58.0 (00: 20.000) =""""""" : :C5~......m.........._.......m........ PROOUCITON CASING: 6026.0 (00:9.625):':';¡ :r;] -;,.... m..'" ................. -..... ........... - -.. -................. -... - -... -....... _..-... -.. -' _..m'" -.. -" -. ...:)................m. -"" 5'5 ~....m.m.............mm.. INTERMEOIATE CASING: 1317.0 (00: 13.375) m_mm-----.._...m"" ¡eD +_.mm..mm._.......mmmTUBING: 24.9-984.2 (00:3.500 ID:2.992) = i8 ~ ...;.......- --..................-.-........,.- -.........-.-..... ",,-'-'-"-'----'---"'-' ......-. --.- --.-.-... -. - .-..- .---. -- ----.-- _.- ..- ..... - -.. .... .,-_... .., : CAMeO INJECTION MANOREL: 984.2-991.1 (00:6.062 '.9t1 "'r.....m...... IO: 2. 992) 'mm.m-._..m...--_m""--"" 991.1-7668.4 (00:3.500 IO:2.992) '95 i.m.mm......_........m. TUBING: : : .....-............................-.-..-.----.-.............-..........-...-....---.-...-.-...-..-..-.--.....-......-........-.......-....-.....--.-.-...- : : 1'Jlti ""'000"_""""""""""""'-"" ...... - .................-.....-..- ....-- - .....-.....--.....,....- .... -...-.-..... .-.-.-- - -- -.. -. -.-. -...-. -. -. -.. , ~ ~t... >.~_.' ""'---"_'_""000"""""""-""'--'-""""'-"""""'" -..-.-... -..-.... .-.. ...- ..-... .-. -.......-........ .,.-...-. -.- .....- - -. _...- - -... ....- .' .. '. , m ..... ....... .............. .......,.............. .... -. -.... ............ 000'" --. -.. - -. --..-- --.... .... - -.. --' -...... -.......-.. -. -........ -. -........ - - -..... .. n - : '-',' :.,<~~:-. . ¡":~jpZS - : .'. ........................,.....-........................ '000""""""'-""""- -....-.. ...-..............-.... ....-.... -. .... ... --. ..-.- .-..... -_........-- (00:7.000) ,. PRODUCTION LINER: 5821. 0-10522.0 ^- CiQZ5 " - , '1'6~ .1-"'-"-"""""'-"""--""""""""'-'-""--"'_000...----.--...---.....-.----..--.....---..-....-.....-.....--..-....--....--.-.....---..-...-.-... : ',"'. : ,~-"'-. .. ¡--'~1.~10t..m"'-BAKER CMO SLIOING SLEEVE: 7668.4-7672.7 (00:4.250 _...--m.._m...m--.........--...--m . ., ¡ ':, ~~: ~- : ... ..mm""""""""'TUBÏÑG'; "'7'6'72':7:'7'6'š-ï~'5 -'(ÖD;3~'5 öö'--i.~;.t- ~~}}..~ - m......m....m..... mm.' --" :"~"'~' .,: -- .- $<"" ':. :.' .i:(.~-$'<-': :~':w':':~ ;: :«~~..--...:: ¡ ":\;:. . ¡ ~'....l6a:!)+..m BAKER SAB 84-42X32 PACKER: 7682.6-7687.6 ¡fl-: 80-32 K-ANCHOR: 7681.5-7682.6 (00:4.850 10:3.000) (00:5.687 10:3.250) TUBING: 7687.6-7733.7 (00:3.500 IO:2.992) ...~'73'+m..m..CAMeO X NIPPLE: 7733.7-7735.1 (00: 3.950 ID: 2. 813)._..m.....m.--_--_m..--....--."'" "40 -:t..._.m--.....-............ TUBING: 7735.1-7806.6 (00: 3.500 ID: 2.992) .-..--.--.--....--.--_.m"""""""- ";'4-5 .¡J...- ....... --""""-""""""--"",,,,,,-""--'-"""""'--' .--.......-.-..... ..- --.-.--.-.... ..-..... -.........-.. .....-.......- -.. ... ... - _.....-.. ~ IJ I::::: ::::::::::::::::::::::::::::::::::: :::::::::::::: :::: :::::::::::::::-::::::: ::::::::::::::::::: :::::::::::::::: ::::::::: ::::::::::: ::: :::: : :'~:~!::::::::::::::~.~~~~.~...~~~~~m~~~~~.~...~.~-~ ~-'.~~.~-~.~-~:_~. ..~~.~;.t.~~~_)m= :::::::: ::::: :::::::::::::::::::::: , ~.< --..;..~ 'Sll:' .< .:. 7e:u~ ..." ::: -- ,.... ::: 't~========~~~~===~ ~ j: I:: :::::::m :.m::.m: mmm:: :onm::::m :.mm: :m_m m m: :mm:::m n n:::::n: n ~.jf., :::: t'~~:~ t.-..........-..-...........-...........--.......----.......-...-..--------........-...----.-...--...--..........-----..-.....-.-....--..-..-..-..-.-.-.-..... 92S'OJ Perf 7911.0 - 7951.0 -- Pert 8220.0 - 8262.0 , w: "",. p~ "II ~ '2 .,,' ~ ~~~ ~ ¡~! 1,!~51 :ft- ¡¡¡' : 1~:;a(i:~ ::1~-«~'-::":§¡ . 'y~:s:!t]: ~ 1-S'r2~~[ ::~9:~~3~ CEMENT RETAINER: 9325.0-9329.0 (00:6.016) ......................- """"""'-"" -.. .......... --..... -.-...... ...-... _.m -. ---..... -.- - --.." - -.... ..-........-. - --. --.. -. -.... -. - - -... -........ -... -... ...................................-..-....-.........................--.-- ..m'--'---""" --,--"---,-,-,,,------"'---'-"---' .....-..-.. ----....-......""'" 3/25/9,6 WeliView 5.0 50-133-20121 ,-. 5L .. '---.. '..... I::::: '..... . --- . .. . - - . . .. .. . . . - .... .. . . . . - . . . . . . . - . . . . . . I ¡..... ..11 .. . ~ '1 .;'" :~ ..............-.-..............................-.............- - :::: ::::::::::::::: :::::......................... ...Oo"'" ...\ . .-.. .",....... I --...... ..--......... ....... --....."............... ::::...... .....:: :::::: ::::1 .........~ ~..LEIVED (" MAR 2 6 191I\RA THON OIL COMPANY 3201 C Street, Suite 800 Alaska 011 & Gas Cons. Commis~. Box 1961 68 Anchorag,8 . Anchorage, Alaska 99519-6168 Telephone: (907) 561-5311 Fax: (907) 564-6489 Letter of Transmittal March 26, 1996 TO: Larry Grant Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 FROM: Chick Underwood Exploitation Department WELL LOGS Description Print Film Kenai Gas Field (¡¿ ~ 04 L( '7KDU-2 COMPLETION RECORD 2 1/2" HSD 1 1 Beaver Creek Field 4> 7- 1 B~:1A COMPLETION RECORD 2 1/2" HSD PRODUCTION LOG TEMP/GRADIO/SPINNER 1 1 1 ...1 TOTAL 3 3 This data is considered confidential until the normal release date. Ck^(~ Jßß J/z f( /7(¡7 (Date) (Marathon Oil) ~o~ (Received By) ') /) "'I (H (Date) ';1 III ( ( MARATHON OIL COMPANY 3201 C Street, Suite 800 P.o. Box 196168 Anchorage, Alaska 99519-6168 Telephone: (907) 561-5311 Fax: (907) 564-6489 Letter of Transmittal January 25, 1996 TO: Larry Grant Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 FROM: Chick Underwood Exploitation Department WELL LOGS Description fA 0 f,," Kenai Gas Field 1 VI/' Print Film KBU 41-7 KDU-2 " t.l~ V~'Ö PERFORATING RECORD PERFORATING RECORD GAMMA RAY/CCL 1 1 1 1 1 1 TOTAL 3 3 This data is considered confidential until the normal release date. C! (:'Uc ~ iLß (Marathon Oil) 2/27 (9b , (Date) <""/, / 'VED ,~E6 2 1 \996 A\aska Oil & Gas Cons. Commission Anchorage , ,I, ,,' ~ œ. (" STATE OF ALASKA t' .....ASKA OIL AND GAS CONSERVATION COM"",SSION APPLICATION FOR SU N DRY APPROVALS 1. Type of Request: Abandon - Suspend - Operation shutd,Qwn - Re-enter suspended well - Alter casing - Repair well - Plugging -X Time extension - Stimulate...x. Change approved program - Pull tubing ::...r Variance - Perforate JL Other ~ 2. Name of Operator 5. Type of Well: 6. Datum elevation (OF or KB) Marathon Oil Com an DevelopmentX- 1 Exploratory - , 3. Address Stratigraphic - 7. Unit or Property name P.O. Box 196168, Anchorage, AK 99519-618 Service- Kenai Dee Unit 4. Location of well at surface 8. Well number 4051 FNL, 43811 FWL, Sec. 7, T4N, R11W, S.M. KDU #2 At top of productive interval 9. Permit number 3951 FNL, 10241 FWL, Sec. 8, T4N, R11W, S.M. 68-49 At effective depth 0 R I G , N A L 10. API number 50-133-20121 At total depth 6021 FNL, 16501 FWL, Sec. 8, T4N, R11W, S.M. 12. Present well condition summary Total depth: measured true vertical Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length 581 13171 60261 47011 measured true vertical feet 11. Field/Pool Kenai Gas Field 10,5221 feet 9,8981 feet 9,7501 feet 9,1261 feet Size Plugs (measured) Junk (measured) 97441 Cemented Measured depth True vertical depth 20" 13-3/8" 9-5/811 Driven 650 SX 1000 SX 581 13171 60261 581 12911 54181 7" 1000 SX 10,5221 98981 See attached RECIEIVED L.S. 2-7/8",6.4# to 95391 Tubing (size, grade, and measured depth) S. S. 2 - 7 /8", 6.4# to 5112 1 1. BOT RH-2 Dual - 50961 PackersandSSSV(typeand measured depth) 2. BOT HI-RSP Singl e - 56131 1 1 . 13. Attachments MAY 15 1995 Alaska OjJ & Gas Cons Co l. An h "~a mm ssion C or2\ " BOP sketch -X- Description summary of proposal- Detailed operations program .x- Approved by order of the Commissioner Form 10-403 Rev 06/15/88 15. Status of well classification as: 14. Estimated date for commencing operation 8-15-95 16. If proposal was verbally approved Oil- GasJL Suspended - Date S-'- i -7 :J Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ¿ Location clearance - Mechanical Integrity Test -.- Subsequent form required 10-~ Approval No. Original Signed By David W. Johnston Approved Copy Returne . ~k'?-.~ qS Date b O¡ Cf. .r;' SUBMITIN TRI PLICATE fl Form 3160-5 '(May 1989) Ul TED STATES ~UBMIT IN TR(' DEPARTMl... T OF THE I NTERIOR ~~r~~e~d~)8trucU BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS (Do not Wle this form tor propoRnl8 to drlll or to de('pen or plug back to a different re8ervolr. Use "APPLICATION FOR PERMIT-" for lIuch propoøa!a.) CATE. on reo- FORM APPROVED OMB NO. 1004-0135 Fxpires: September 30, 1990 5. LEASE DESIG1UTION AND ..aUL RO. A-028142 6. IF INDIAN, ALLOTTEE Ot nl8E NA3IE 1. 7. UNIT AGREE~ENT NA3II& OIL 0 WELL CAS Vl WELL Ã..J OTB EB Kenai Deep Unit 8. ."M OR LEASE HAM& 2. NAIIE or OPERATOR Marathon Oil Company 3. ADD&E8S or OP~RATOR 9, waLL NO. 4. P.o. Box 196168 Anchora e AK 1 - 1 LOCATION OF WELL (Report location clt'arly and In accordant'p with any tate requirements,. See also spact' 17 b('low.) A t surface - KOU #2 10. rlELD AND POOL) OR WILDCAT 4051 FNL,43811 FWL, Sec. 7, T4N, R11W, S.M. Kpnai r,a~ E..ield 11. sac., T., t., M.. oa aLl[. ~ 8UaV8Y 0& A.&IIA Sec. 8, T4N, R11W, S.M. 68-49 \15. ELEVATIONSI ~hOIW whether Dr, RT. GR. etc.) 12. COUNTY OR PARISH 13. .ToAT& 14. PERMIT NO. 16. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data SHOOT OR ACIDIZII 1- .x- 1'1'1.1. OR ALTER (' \SI:-IG ll.. )ILL,IP1,E (,O~IPI.t;TE L ABANDON- 8UB8EQumNT a.POtT or: wATER SHOT-orr § FRACTVRE TREATMENT SHOOTING OR AC'IDIZING REPAIB!NO wmLL NOTICE or INTENTION TO : TEST WATER SHUT-orr FRACTURE TREAT ALTERING CA81NO ABANDONMJ:NT. (Oth('r) (NOTE: Report re8ulta of multiple completion on Well (Otbf'r) ('ompl('tlon or Recol.i1pletlon Report and Log form.) 17. IH:S('RID.: I'ROI'OSED OR \tHII'I.ETI.:O OI'ERATIO'f. (CII':lI'ly ~tat.. all p.-rtlrll'lIt df.tnil~, nnd ;I\'I' Pf'rtlnent dates, Including estimated date of starting any proposed work. If well is directionlLily drilled. give subsurface locations and mf'llsllrt'd and true vertical depths tor 0.11 markers and p)Oe8 perti- nent to this work.) - REPAIR WELL CHA:"ICE I'LA:O;~ See attached addendum. RE(EIVED MAY 1 5 1995 Alaska Oil & Gas Cons- Commission Anchora, :~ 18. I hereby certify that the foreggtng !s t~e and correct SIG,NED ~J:. ~ TITLE o-~ 5~¡ DATJII 5"-/ ~'J (Th18 8pace for Federal or State ofBce use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE *See Instructions on Reyene Side Title 18 U.S.C. Sec,:o:1 1001, makes it a crime for any person knowingly and willfull~' to make to any depa:'tment or agency of the UnitE:Q States any fëisE:, :"ictltlOUS or :raudulent statements or representations as to any matter wlthin it5 Jurisdiction. ,i ~ ~: KDU 2 PERFORATIONS 5119' - 5120' 1 ' Pool 6 C-1 Sand S.S. 5128' - 5138' 10' Pool 6 C-1 Sand S.S. 5170' - 5190' 20' Pool 6 C-1 Sand S.S. 5235' - 5265' 30' Pool 6 C-1 Sand S.S. 8245' - 8255' 10' Upper Tyonek Squeezed 150 SX cement 9510' - 9522' 12' Upper D-2 Sand L.S. 9558' - 9588' 30' Lower D-2 Sand L.S. Below Retainer @ 9750' 9854' - 9874' 20' D-3 Sand 9884' - 9910' 26' D-3 Sand 9910' - 9919' 10' D-3 Sand Below Retainer @ 9950 10,028' - 10,036' 8' D-4 Sand 10,080' - 10,092' 12' D-4 Sand All Depths are Measured Sand Tops Pool 6 C-1 5125' MD 4545' TVD D-2 9501' MD 8877' TVD D-3 9787' MD 9163' TVD D-4 9995' MD 9371' TVD Note Static BH P - 450 psi - 9/93 REGEIVED MAY 1 5 1995 Alaska Oil & Gas Cons. Commission Anchora, '"' /nrs G:\CMN\DRLG\2PERF - ] ~ J TUBING C.::T,\IL. ] SHORT STRING í --' Existing Wellbore Schematic K.D.U. ~ 2' (W .0.) ,",' "] A. 2 7/8" EUE 8rd Soal lock ObI. Pin;1r 16. û' B. 2 718" Otis ':<0" Sleeve or 5029.63' C. Brown 'RH-2" Pl<r. ar SO~6"21' D. 2 7/8" Oti5 'N" NicOlo ar 5112.28' 'J DATE 8/13/68 PERFORATION RECORD INTERVAL CONDITION 1 ] 10,080'-10,092' 10,028'-10,036' 9,884'-9.910' 9,854'-9,874' 9,558'-9,588' LONG STRING KDU 2: Current Status: LS: 1.2-2.1 MMC~~I J ' 1. ~ ;;:: ~~i~ :~<~::~~~::XatO:~:~~3:t 'Jt?\3' I I A;':'¡ (~:.! Li. ! j \ j. 3.68" 00 Blast Joint 5136'-5156' ! : ! 20" C~slnq at 58. ] ,~. 3.68. 00 Blast Joints 5166'-5206' LJ II 5. 3.6S" 00 Blast JOint 5237'-5287' 8 !£2.! 6. 3.68" 00 Blast JOints 5318'-5338' : : ~ ] : !.; COI 2 7. 2 7/8" Otis 'XO" Sleeve at 5536.54' ! n B. 2 71B. Seal Leek P"" Safetv JI. "' 5602,:2.' cr<., :,,'~~/] !)< 9. BOT HI-ASP Pkr. 3.r 5612.95. : i .I.. ..;- J 10. 2 7/8. Otis 'xo' Sleeve 81 9444.1.~' I ! I ¡ 11. Bakor Locotor .~ub 01 9509.64' I D tUl ¡ ~ 3 5/1"1 OJ 12. Baker Moael ':>. ?kr. 'tV/Seal AS5V. al 9511.64' I 13. 2 7/8" Otis .N" NiOPle al 9537.88' 14. 2 7/8. Otis Mule Stice al 9539.08' 10.080'-10,092' 1 8/4/74 8,245.-8,255' Sqz. Upper Tyono W/150 SX. 'G" emt. Isolated 1 between Plus. at 9,512' &. 5,613' . --J -I 8/13/74 5,119'-5,120' Pool 6 C-1 Sand. 8/15/74 5,235'-5,265' Pool 6 C-1 Sand:¥- 9,51 0'-9,5~2' ] 7/28/74 7/29/74 ] 7/31/74 9,854'-9.874' .. 8/1/74 10.028'-10.036' 10,006.-10,007' 9,910'-9,919' 9,884'-9,910' ] 5,170'-5,190' 5,128'-5,138' 1 0-4 Sand 0-4 Sand 0-3 Sand 0-3 S¡¡nd Lower 0- 2 Sand :-- Uoper 0- 2 Sand * 0-4 Sand 0-3 Sand D-3 Sand 0-4 Sana Pool 6 C-1 Sana .~ Pool 6 C- t Sand + SS:. 0.7-2.8 MMCFD ~3 J/S" C.1SlOg ilt 1317' If ¡it /t2ru-ol > -- ~ (p ~ . , "... '~ 9 ..- t - -: ...' .' '. .' . . -" 01 10 I l" ~ 5/8. Casing at 6026' ~.. \ 12 RECEIVED MAY 15 1995 A\aska on & Gas Cons. Commission Anchor",- '1' 13 , 4 7- Casing at 10,522' unl§n -" , .. . , K'.D.U. #2 (W.O,) WELL SCHEMATIC NOTE: 0-3 Sand Isolated Bulow Rotamer at 9,750' 0-4 Sand Isolated Below Retainer at 9950' * Open For Gas Production 1 .....-..- .--------........-....---...--...........----......-..-......--.........-..-.......--..-.-,:,....-,..,.........--...,11:'\."-""" . ::'\., I.... -- ." -..' 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. ( (" WORKOVER PROCEDURE FOR KDU 2 R/U Slickline. Verify sliding sleeves closed on both strings. Bullhead KWM down both strings. Open sliding sleeves and fill annulus with KWM. J..:!'\ [ l,A.."r-{' l,.vt I..,l &. Set BPV's in both strings. Move in and R/U workover rig. N/D tree. N/U BOP's and test same 250/3000 psi. pû.(' -J-L7 1- r"€- es Clean OUt wellbore to retainer at 9750'. Set packer and tailpipe assembly at 9500'. Set plug in same. Squeeze Pool 6 C-1 perforations. N/D BOP's. Change out tbg spool. N/U and test BOP's. Drill out squeezed perfs and test to 2000 psi. Set production packer at 7800'. Run 3-1/211 production tubing. Set BPV. N/D BOP's, N/U tree and test. R/D workover rig. Perforate Upper Tyonek 75-8, 8220-8260' MD. conservative rate. Flow for extended time at Run pressure buildup to determine skin and Kh. Determine need for stim frac, EOB, or EOB resin sand control. R/U CTU for cleanup following stimulation and flow tests. If 75-8 sand is not productive, perforate and test 72-8 sand. /nrs G:\CMN\DRLG\2WOP RECEIVED MAY 15 1995 J\\aska OU & Gas Cons. Commission Anchora. '1 ( ¡~. I 1\ .' ~:'! 1:-" ,\ (~ , ---' -, - , \ '--" :\ I J L) \- -~ r--- . ~,-., -. .- r- ~ '~~I..':~:i' '1"-. f- L' ,\'_¡I "_/~L- vVE ~~E~ 0 R E \f -';-. - .- ,~ . , . --- . , - -, { I I \ 1 . - !, .~h CIV A ! I ('j R f\8 @ O' HeR @ 15.7' J L 2C' Csg @ i I ! , I I I I I . J h ! I ...... I I~ , -;:-] i .. " /' ~ t' ; :........... I ' ; --- ~ =rev. ~;azd U. ívonek ~ .:3,245' - :'3,255' MD I.' ".- ..--"; 1'....1"~4.,....." ~.. .,_00... ,:,¡-¡.'." . ~... ':'" Deep Tyonek D- 2 (9.522' - 9.588') Tyonek 0-3 Abdn below retainer @ 9,750' Tyonek D-'¡' Abdn below retainer @ 9,950' I I I i !! J 58' I , I L :' 3/8" @ 1.317' Sterling Pool 6 C-1 Sqz perfs at 5,119' - 5,1.38' .3 1/2" tubing - ~'! 7" liner top @ ::::=---' MD 'J 5/8" csq @ 6,026' PrJcker set approximatelY 7,:300' MD Suspected completion scenario: Upper ívonek 75-<'3 03,220' - ;),260' I\o1D), Perforate; extended flow test at conservative rate; PBU to determine '3kin and kh: determine neea for stimfrac E08. EO8 resin sana control. Uphole recompletion potential In Upper ¡vanek 72-8, 73-1 (ì,910' - 7,992' MD) I dictated by performance of the 75-8 sand, I ct.sOO IYIIJ : ...... 7" liner @ 10,522' MD CAM .3/04/95 R EC2E IVED MAY 1 5 1995 Alaska Oil & Gas Cons. Commission Anchorë. .~ -';':~-~-,... .,:"':..-.."..- ---..- , , .- ----,"-,-_.~.""-"...".,...._..,...,,..,...... ," ". , I(' ~. ~ ,~ PROPOSED BOP STACK CDNRGURATION 13 5/B RSBBð H'IDRIL 13 5jr-5D00PSI GK NtNWR BOP SCR£r ISÐ 13 S/r-10.00DPSI HUB BOTTDII CONHECJJOH CHOKE WfNG H'1œL 13 5/r-S.DOØPSJ DOUSI.£ lWl BOP HUB CDttœ:nONS ... 1/Ur-5.00ØPS( SŒ Oun.m WIJH *HUAI. 1DCXS KILL WING IIc£'JDY ... 1/1 ¡- -5.00 1YÆ E GATE WoW: 13 5/8'"-5.00OPSI " 11. -5.000PSl r.o. IIc£WY J 1/1t'-S,oOOPSl nÆ £ ~TE VAL'Æ HmRJL 13 5/8'" -S,oOØPSJ IIPL IWI BOP HUB CDtMCnDNS ... 1/1 t' -5.DØOPSI SIJE OUlUJ'S 11TH J.W4UAL LDCKS BLOW-Our PREVENTER STACK PM WORKOVER RIG RECEIVED MAY 1 5 1995 A\aska au & Gas Cons. Commission Anchoral'11 IUV 10-:! . ,,' STATE OF AlASKA t,t, AND GAS CONSERVATION CONJv\'TIEI i"'C""'", r' ~'" I-~" . ¡. "', :'~:~ {(11 :'r":' i: 1.'.7 ;-,~:' :-"::~1 ' I) '¡ I ' , ' , ~ '; , I :-. 'I I' 1.;;.'! '\:;;~.. H",',: ,l." \.1 ': ::" ,~ ,- ': ' I.~;: ' : ! \ ~ ':¡" i 1.\", ' U \.,;l L.~:.,) .,~ I,} ~'~! ~~ C'¡;~)7í) .. ", " ... GAS WELL OPEN FLOW POTENTIAL TEST REPORT . :\Iullt-POIXT TEST Test SpecIal ~ ~ ~.. /:.. ,! '. ' " :; " ,", , '. ".., -' InItial 0 Annual Hesen"olr 0 " . Union Oil Company of California A-028142 C'uunty I Loc~liCln 4391 S & 68301 E from NW Corner, Kenai Sec. 7, T4N, RllW, S.M. Pr(¡dlldn~ 'l'hru I R«~n'aj~ I W.Uhrld ~CSG. Size I '\\"t/Ft. TXBG. I egG. jrmpualure jcmp~pturt 4 102 OF ö5 IF 5/8-7" 0-29 TUG Size I " tiFt I O.D. I I.D. I Set @ I Gas Gmlty I ~> ~ ~ . 5 ~ 2 7/8 2 . 44 1 51 1 2 ' Mþ (SÖ:rsog 5 Pipeline Connection I Type Taps r Nikiski Pipeline Flanqe )luJllple Completion (Dual or Triplt!) I T)'pe production frem each zone Dual Gas OBSERVED DATA Flow Data. I.D. I CompleUoD Date 7-18-74 I Sel @ 60261 - 10,522' Mi. Prod. I GL I Ga_.Llqllic1 HI drocart>cn Len¡th (L) Rat io )(( F p~r Bbl. 0 I Tolal Drpth 9744 I Test Dale 7-18-75 I Well ~o. KDU-2S I T¡;~Y ¡5rf~\~§:t-526~ ¡"It"lù Kenai Gas Field O¡>crator Pool 6 Lea!>e I Gr3\i!'" or Lil.'Jid Ò\Pil . Time (Prover) (Choke) Press. DIn:. Tubing Casing Flowing- ~o. of Flow (Line) (Orifice) h Press. Press. Temp. Hours Size Size pslg w psig psig of SI 14 2 1. 1 1396 89° 2. 1 0 CO v:;,> 3. 1 84° 4. 1 810 FLOW eALCtJLATIO:-;'S Coerfl- -Yhw Flow Temp. Gravity Compress. No. clent p Pressure Factor Factor Factor ~ Rate (If Flow F F F ! (24 Hr.) m psla .t g pv ' Q ~IÇF/ D I 1. 1 4 11 1.0 05 2223 2. 136 1 .0902 3342 3. 1320 1 .0886 4237 4. 1214 1. 08 6 6 PRE~St"n.E C.-\LCl'LA TlO:-\S w I P \\ ~ I , I p ". P t (p~la) p: , It FQ c (F Q)2 c (F Q)= X 1- e-s c p: W P' - P' c w , Cal. P - 1. L- :t - 4. Ahslllule Potl'nlial 14,100 I, II ~ICF'.'D .6590 CER11FlCATE: I. the undersigned. state that I am thp enq i neer ~ the Union Oil Company (company). and that I am authorized by said company to make this report; and that this report was pre. pared under my supervision and directjon and that the best 01 my knowledge. the facts state~',ere1.n are true. co, rrect and complete t? f}¿1l ¡I 4~ ~ ~ --.: - t:-",l£¿-,/t ( . '('{ t-t ~--- Signature Ga ry E. Ca r 1 son { Kenai Gas Field Back.Prl 'ure Tests Well. KL.. #2 Pool: 6 Survey Date: 7-18-75 '-.. 1.0. :¡rnn,¡J¡ 1j ; :¡ j ¡ ~Î:¡¡ ¡¡ 1 ¡ 1- U-t i~J~! ; ,,' ',' I ; " f .,t . L. t. ~-t ~ ~Lt.i ~t LJ : . ¡ j' I r ~' ~HL; ¡ ïJ! ¡ , '; i ; ti! ~~; : . ¡ " d':::: ; ; . .., . . ¡. . ;. ¡¡ , :: ; j :/: ! : : I I ::: I",,," 1 : j I j , 1 : . . . ~ . .. .! , '" !~ ,,' ':,:~:,', :::::: i'( 1 :,:: :J .. .' ¡, t- t t:: f".E I . ! I : ~ .. " : :' , , .. i' I I.. ¡ j: : :; : !: :::' . i Ii . " .. , ~ I ¡ . I." " , , , , , i :.- '¡" ¡ ¡ i I ¡ ¡ ¡ ! 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I,; :,,:; :~0S,::, ': :i: ::11: ": ¡ . , : i ¡:,. : ¡ I ' . . ~; "., , I I ' : : 1 i' : I i I~:: : ": ¡:1 i: -. . . . : !:; ¡ ¡ , ., ~: : J I . .. .. ) 0 r-I X 11 C¡..¡ P-t I \l "CI.) P-t ~ ~j I->U õ:t ~N gx .IN .~ '.02 1..0 2 5 lÒ 20 50 10Ò GAS FLOW RATE JAMCF/D G^S~" ~LL OrEr~ FLO\'J POTEtJTIAL TEST R~.~~"~T . PRESSURE CA LCUlA T IO:JS (Supplement to Alaska.O & GCC Form No. G-I) Field Reseïvc lor Test Catc Kenai Gas Field Pool 6 7-18-75 Operator Lease "IG II : ~O . Un i on 0 i 1 Company of California A-028142 KDU-2S ( I) (2) (3) (4 ) Test Ps Pf (Ps2 - Pf2) Q No. Dsia t)c;ir'! X 104 :,.'cr /0 1 1447 1411 10.29 2223 2 1447 1363 23.60 3342 . 3 1446 1320 34.85 4237 4 1446 1214 61.71 6363 Sub-Surface Test Data ---..----.- - 0 Subsurface pressufes measured. CJ Subsurface pressures computed: Cui lender-Smith ~ethod of IOCC. ( I) (2) (3) (4 ) Test Pws 0 (P\oJs 2_P\V f 2) Q No. nsia psia " 10-4 ~,'CF 10 ¡\ . 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I , 1'1 , , " : i : ' ! l i : ; " , ' I !, ";i ", ' I ' " I' :, :, "I' :, " i¡'"":';'¡'ìí!!ì¡, "1::,,,\""':1';1'1",1 ,"i,.:','I', ;:1" ,1",11"11,":"",:1',:, :I'¡ii,II"I""""i'¡.",.":,, 1_,__li,J/I:lil "'::1,11 '~:'~'.:I 1:;;:1 l'I'llli:I¡;¡: 1:!,!~¡!I""'i" ",'t" J!-!:¡-;~_It"; ¡¡¡:1¡;' .. ;,,1'11 ¡' T t¡II;¡I,i:::¡:: :..LI ;f' ¡I¡il¡::j¡i!ii::ii,:;¡:i,j,j;" :¡",!;,:;'::::;: ¡tl:l, ..¡ ,J !"": > - I. , , I, '.. I : :' , " , I: ; " i" I , I' : ¡'I I, , " ",', ¡, ! i ¡ I I , ; , ,.. .. : 1 ',: '~i' -I-L¡,,!,:,j.:;i,I!!l ",ii,;,:;'" II',' ",:¡':I':,: "',:,,,; j¡~!':;I::,::;¡¡¡j:~,I"':"~J;I,J !,!¡¡!¡!!..;,L~...,.., -1--:,;,;'I-I!-\:;I:I; o¡,!:'!¡:¡il,' ¡"i{::,,¡-!:¡ji :"I¡t~:,:,!,I,iì:,i;:'I~,f¡I;;,:, ;u. , I I ' t/ ' , ~ +.;.~Æ<¡; ¡ ¡ ¡ !! !Ai ¡t:' I :' ,:! I 'I '" ' ." ",.., .. ":' i';;:I';I"":"::';::::" ¡;; ¡ ¡ i:i :I::,:¡!:, : ¡;: I' :, ;, '. ,,' :" i :, :, " i, >, i, :" :, :, I' : ¡; i;:::; ;,: I , .. ' :;;'::' ~ , ~ ' : I ' ! " I,,' I" I I -, '~' .... ;: i: I: t,: ;,: ::i:: ! ¡-¡'j:Y;:,!¡!: :'~ .05 .02 .01 1..0 2 5 10 20 50 lC,;, GAS FLOW RATE Ji1MCF'/D fiE V 10"Gt STATE OF AlA$KA f .. AND GAS CONSERVATION COMMITTd' f'~"::>, :~'::¡ \f,'"i,::'ì.:,:, '--':1,:: r,' ,'; :T' ~':::\. , 'i,I" ! , "", ".' i,.' '.' '.., , '," , , " "', I ,~ '." t_jJ:': ';: :,..: ~,"'/::) GAS WELL OPEN FLOW POTENTIAL TEST REPORT Opcrator Lea~e Union Oil Company of California A-028142 (.uunty I Location 391 S & 6830. E from NW Corner, Kenai Sec. 7, T4N, RllW, S.M. ProducinJ:' Thru I Rf<molr I Wtllh~.d I eSG. Size I '\\"t/Ft, J I.D. , 'AUG. I C~G. I T~mpPi'I}J{e 'Itm¡ma:ure / 8 4 X lLfÖ'F 52.F 9 5 -7 0.0, 29. TUG. Size I Wt/Ft. I O.D, I I.D, I Se~ @ I ~~~~~:~~~~ I 2 7/8, 6.50 2 7/8 2.441 9539 0.555 Pipeline ConnectIon I Type Taps Nikiski Pipel ine Flanqe Multiple Completion (Dual or TriDI~) I T)'pe production from each zone Dual Gas . )Jullt.POI~T TEST Test Tnltlal 0 Annual Jte~en'olr .'Itltl Kenai Gas Field T onek ....... OBSERVED DATA. Fto\\' Da ta ~o, Time of Flow Hours pslg (Pro\'er) (Line) Size Press. (Choke) (Orifice) Size Ditt. h w SI 1. .4 8 '2 h':2P. . , .... I -, I .61 8.41 1 . 1 26.50 1 1 1 1 3.438 3.438 .. "'. 3. 4, FLOW CALCCLATIO~S No. Coerrl~ cient (24 Hr.) Flow Temp. Factor ¡" t --y h w p m Pressure psla 1. 2. 2284 220 2064 1941 3. 4. PRI;;¡;st'RE CALCl'LATIOXS P \\' p:1 ,t F.Q c (F Q)2 C (F Q)~ X 1- e-s c - (pxh\) P t J. 2. ~. 4. AlJsulute Potential In :\ICF/O .5596 18,000 CERTIFICATE: I, the undersigned. state that I am thp e nq i nee r " """,' , " 0 . 'c, ""' ~..:, ", ,I Special § I Completion Da:e 7-18-74 I Set @ 9 5/8" - AI'¡. Prod. I GL Len¡lh (L) I I Test Date 7-18-75 I ~~~ ~o2L IT/Pay rrl"'!U,I~¡ 42 . B5Tö~~95881 I Total D~pll1 1b,4771 60261 7" 1 iner 58211-10,52 I G.1,.Llqllirt H)'d~onrbc:¡ I Gra.i:',' or Ralio ~I(F p~r B!:.ì. Lil¡:Ji¡j IApi) 0 0 . Gravity Factor F g Tubing Casing Flowing- Press. Press, Temp. pslg psig Me"fer 6 0 - 630 63° 63° Compress. Factor ' Rate (If Flow F , Q ~ICF/D pv 1.1464 3859 1. 14 82 1.1443 8064 1.1371 9559 P~ w , ('at I P w P J- w P c -1 pz - p2 C "" of the Un i on 0 i 1 Company (company), and that I am authorized by said company to make this report: and that this report was pre. pared under my supervision and direction and that the facts stated ther in are true, correct and complete to lb. be,t or my knowled.e, t. 6t.,~.-</ SIgnature Ca r 1 son . ~AS( 'C:LL OPEt~ FLOVJ POTEtJTIAL TEST R~/'ìRT PRESSURE CALCULA T IO:JS (Supplement to Alaska-O & GCC Form No. G-I) Field ReseïVC I.r Test Catc Kenai Gas Field Tyonek 7-18-75 Operator Lease ',",'e II :.0. Union Oil Company of Cal ifornia A-028142 KDU - 2L ( I) (2) (3) (4) Test Ps Pf (Ps2 - Pf2) Q No. osia t) ill X 104 \~CF /0 1 2361 2284 35.77 3859 2 2362 2203 72.58 5782 ,3 2362 2064 131 .89 8064 4 2361 1q41 . 180.68 951)q Sub-Surface Test Data D Subsurface pressures measured. CJ Subsurface pressures computed: 'Cu II ender-Smi th :"':ethod of I acc. ( I) (2) 2 (3) 2 (4) Test Pws 0 (p\.¡s -P\,¡ f ) Q No. nsia psia " 10-4 ~. 'f" Fir..., 1\ " v \ J . - - . Nomenclature: Ps = Static surface pressure '..p.f--_.= FIO\'f'ing surface pressure Pws ='Static bottom-hole'pressure (mid-point of perforations) Pwf = Flowing bottom-hole pressure (mid-point of pcrforÐtions) Q = Flow'rate, ~:CF per day at 60°F and 14.65 psia - .. 1-70 ,. ' ( ( PRODUCTION TEST AFTER WORKOVER KDU - 2 POOL 6 D- 2 DATE MMCF D BW D ~1MCF /D BWPIT . 9/26 7.29 7.00 9/27 7.40 10/2 ,7.30 MONTH JANUARY . FEBRUARY MARCH APRIL MAY JUNE JULY PRODUCTION SUMMARY POOL 6 ~lCF1D~' - - -- - - -- ...--- - - -- - - -- - - -- - - - - . WORKOVER 7-19-74 TO 8-20-74 \ AUGUST SEPTEMBER - - -- 7.30 Wl fEe IE 0 WfEflJ) DEC1 j 1~1è} DIVIS,<-.. t~!;: F~C~~I~ ANt),' GAS A¡\(_HOR¡,\oe . lO-29-74(GAG) D-2 MMCF /Dw- 7..02 6.71 5.50 7.59 7.09 6.51 9.19 9.59 'i 8.11 1,7:j" .. ' lU-LY-/4 ( ~. ~ WORKOVER SUÌ\lMARY KDU-2 AFE NU1.1BER: TOTAL COST: TOTAL SPENT: 341110-8 $478,300 $478,300 AFE NUMBER: TOTAL COST: TOTAL SPENT: 341118 $159,300 $159,300 " PURPOSE: Abandon D-3 & D-4 sands, treat D-2 sand with hydroxy-aluminum for sand control, test Upper Tyonek, complete in C-l sand of Pool 6. SUMMARY OF RESULTS: The D-3 and D-4 sands of the Kenai Deep Unit were successfully squeezed and abandoned belo"l retainers' set at 9950 t and 9750'. The D-2 sand was treated with hydroxy-aluminum for sand control. The producing rate prior to and following the workover was about 9 mmcf/d from the D-2 sand. No sand is now being produced from this interval. ..,.., An Upper Tyonek sand was perforated from 8245'-8255'. A DST of this interval produced 1.68 mmcf/d against a 300 psi surface préssure. The Upper Tyonek reservoir pressure was abnormally high (above 4050 psi @ 7869' or a .515 gradient). This, interval was squeezed ånd isolated with two production packers. The well was completed in the C-l sand of Pool 6 at a rate of 7.3 mmcf/d with no \Vater or sand production. KDU-2 is now a dual D-2, C-l producer with two .tubing strings. SU~WARY OF WORKOVER , Testing of KDU-2 in early December, 1973 indicated water production from the D-3, D-4 interval. This water was believed to be from the water sand from 9930'-9973' and entering the wellbore thru a channel to the D-3 perforations from 9884'-9910'. A WSO tdst at 99191-9920' had no entry and disproved the suspected channel. Additional DST's at 10,OO6LIO,OO7' and 9854'-9874' failed to locate any extraneous sources of water production. A DST of the D-3 gas sand from 9884'-9910' produced water with a small amount of gas and sand entry. A DST of the D-4 gas sands from 10,028'-10,036' and 10,080'-10,092' had no entry. The D-4 \{as reperforated fro~ 10,026'-10,038' and 10,076'-10)094'. . '" ~ fl@ lOW II..... " If fñJ 11& C 1 1 IQ7o1 Uti OfVtSloN c r: Qi~ AN ANGI10/tll,ae " 0.$ ( ( Summar~ of Workover - Continued The D-4 then produced 3.1 bbl of v;ater on a 3.5 hr DST. The D-4 was abandoned with a retainer set at 9950'. The D-3 per- forations from 9884'-9910' were squeezed and abandoned thru a retainer set at 9750'. The D-2 ~erforations were found from 9546'+ to 9580'+ rather than 9510'-9522' and 9558'-9588'. The D-2 perforations were treated with hydroxy-aluminum for sand control. The D-2 sand from 9510' to 9522' \Vas perforated and treated with hydroxy-aluminum. The preflush contained 1 BPF 5% HCL. The Upper Tyonek sand from 8221' to 8261' was perforated from 8245' to 8255' for a DST. This interval produced at the rate of 1.68 mmcf/d against a 300 psi surface pressure. The reservoir pressure was above 4050 psi which is abnormally high. The pressure gradient to this 7869' vertical depth sand was .515 compared to the normal pressure gradient of .451 in the Kenai gas field. The rate was too low to justify a Upper Tyonek completion and this interval was squeezed. . A set of WSO perforations at 5119'-5120' above the C~.l sand at 5125' produced 2 mmef/d and no water on a production~test. The C-l was then perforated from 5l28'-5138~, 5170'~S190' and 5235'-5265'. These intervals were then treated ~ith hydroxy- aluminum for sand control. The pre flush contained 1 BPFo£5% BCL. KDU-2 was completed as a dual C-l, D-2 producer with two tubing strings. The D-2 sand production packer was set at 9500'. A' packer was set at 5400' to isolated the squeezed Upper Tyonek sand. The Dual production packer was set at 5098'. ; \ [1 æ a: ~ tWo E'r~ DEC 111l L. .:'{~......,. ,.......PO'L t 11;,;< CHOR.A. G . ~.~.-..-.........~- ""'~ -1. -... ""-- . - ._~ -(' 8/20/74 CIW Hanger 2 7/8ft 8rd. TUBING DETAIL 15-2 7/8" 6.4# Seal Lock to 9539'. 85-2 7/81t 6.4# Seal Lock to 5112'. TUBING ACCESSORIES: -.. .. .. ...-...-C--"-" - T i?fiß¿ S~7r;1-Bm . . . 8rd X 2 7 / 8" S1 DBL Pin-17'. 2. 2 7/81t Otis ftxo" Sleeve-S061'. 3. 4-3.68ttOD Blast jts.-S136'. 4. 2 7/8" Otis uXQ" Sleeve-5537'. 5. 2 7/8" Safety Jt. (50,000#)-5602'. 6. BOT HI-RSP Plcr.-5613'. C 7. 2 7/8" Otis "xon Sleeve-944S'. 8. Baker Locator Sub-9S10'. 9. Baker perm. pkr. w/ 16' seals-9512 , D 10. 2 7/8" Otis "N" Nipple-9S38'. ; 11. 2 718" Otis Mule Shoe-9539'. I I i ~i- ~ 8rd X 2 7/8" SL DBL Pin 17 t . B. 2 7/8" Otis "XO" Sleeve-S030'. C. BOT H-2 Pkr.-5096'. D. 2 7/8" Otis "N" Nipple-SI12'. ~~~~~WlEíID DEC 111974 DtV~SK...I.. .. I': OIL AND GÄS ANCHORAGe A 1 13 3/8" csg. @ 1317'. 6 Top of 7" egg. @ 5821'. ."""" 9 5/8" egg. @ 6026'. TD 10,522' - E~_:74~ - 7::~::...:..:,O, ~22 ' . ------I ~EV" DATE / / DU\'fN -- CKD. ---q - ---~ WELL SCI-If:Í'IATIC 8 20 74 ,Arr'D. _._._'_......._..,-_..._--_..~, .- --, . . I SCALE -----------.--- ~ , '::t- .. -I Kenal Gas Fleld.Kcllai Deep Unit #2 (WO) MY" -~.....:..~~.._._~_....j ~-~--_..=~==~:I.' --=f---- . # t: SHt:::rs ~hd:1 7 ,-..-.."""'.,,-....-"";""""""'....."" ~_,':~ .""'.... ",:om""...""" ,......_t ::11:_,,",,<""""'" ,~'...-...,,") ,-,--~-""---""".""""'" -.--11<" '"Ot _...,.........',. ~,"'" AJ "I , ~ ~""..... -,.-, I.,.,""" """"1, . ,~. '. " fp,r:.m 0-1001-A 2011 58' 13 3/8" 1317' 9 5/8" 6026' 54.5# 40# \..I UNION ()IL CO. OFG/l REPA IRRECORD J-55 N-SO SHEF:TA (~, :PA'G ~NO._'&'l , .l,.....-, ~ Kenai pri lling Co. Oih~~lL.5 2T . GROUND . See ' CASING HEAD--Pr..çyip_1J..L----, TUBING HEAD______-_---.R~J2orL- ROTARY DIUVE BUSHING LEASE KENAI DEEP l1NTT_____.-- \VELL NO,KI.?9_!2 CONTRACTOR FIELD ._- TYPEUNIT__- BEGAN;-1JJ.ßJJ4 CO:MPLETED: _.__8L2J1L74- ELEVATIONS; PERMIT NO._-ÞJ3_.:-A2.._-.SERIAL NO. -....-A-'-02B14Z_. CO;\lP l\NY ENf'aNFER " ~T.1J g.,$.te:r..:-.kI ~§~~.~----- .------ -----.---.- . ,., ,',- -,'-'~ "'1111~O !'> IL"41118"-' AF'~'PP()V'~D ';..;-:Ù;',<"1 Ji.--::-, L.....:i _:-'-..~ ;,?.Al' _r.:. ~f-)'i: 1 61. 'ft.::>':' -;. ...\. -'-' -L.... .-,. ----' - ---..------' ..,-.,-,. .- "'-~~-~--_._. ----- ""--'-===-~'1:1'rFrt=.Cd--rœ.ffD'er , CASING & TUBING RECORD, St~~ ì DEPTH -t ?{EIGHT_-::l GRADL:::I:__- ---- -IïE~ARKS . - Conductor driven to 38'. Cmt'd w /450 sx. G cnlt, Vv /50% Perlite & 6% gel followed by 200! sx. G cmt. w/ 3% CaG12. Cmt'd w/500 sx. 1 1 Per litewI6% gel followed by 200 sx. neat cn1t. thru shoe-300 sx. 1: I Perlite w /6% gel thru DV. . J ,;t1f>1~~ '1821' o~c:;e.t wi' 'JJl!lQ, ~X .~?SS 'HGH Ç}TIt. PERFORATING RECORD ~ASON 'I -----.-'- _111 ---!lQ . C; 2 2 ' .L-2 PR~EJiT CONDITION ---- ---r-:-" J~rJ;lAL.pnQr," :rJÇ,~T!ON" ~AFTER - REP,AIR ¡x, Lc.I1T lOR!'. V. CoP. LLP. 'j_alQKJ;;LMcr:._LGIDl I ,I AFE #~1l1110 To test 1& abandþn the'l D:-3 ,& ~'-4 SdS,~, ~, the,l uppet,- ,T}~on:lt Sd~. To treat the D-zi Sds. wi HYd~OXY-A\ mmul & çon.plete mI the c- AFE #3~1118 To testlthe Poo~ 6 C-.J. Sd. &. - , n ~, A,I. I I I I I ! I I ! , i ¡ I I i ! I - I [ i I . "" -_...- '. 'lIEL).. HISTORY J:~.RIOR TO REPAIR 1 - - & -. I I E I ßYAL 8/13/68 10,080'-10,092 8/13/68 10,028'-10,036 8/13/68 9,884'-9,910' 8/13/68 9.854'-9.874' 8{13/68 9,558'-9,588' 8/13/68 9,510'-9,522' 7/28/74 10,006'-10,007 7/29/74 9,919'-9,910' 7/29/71 9,884'-9,910' 7/31/74 9,854'-9,874' 8/1/74 ~0,0281-10,036 10,0801-10,092 1)l... TE -----¡ IN'rERV ~......- *NOTE: --- 10,477' 10,477' 10,477' 10,477' 10,477' 10,477' 10,461' 10 , 461' 10} 461' 10,1981 10,436' =o~~-- . Production I Production! Production, I , DST# 1 I " . Production Productio DST#l 'VVS \"'1S0 DST #2 DST #3 DST #4 D-4 Sd. - Isolated below ref.@9950'. D-4 Sd. - Isolated belo\v ret. @ 9950'. D-3 Sd. - Isolated below ret. @9750'. D- 3 Sd. - Isolated below ref. @ 9750 r . L?wer D-2 Sd. - Open for gas production. UpperD-2- Sd. - Open for gas production. D.-4 Sd. -- Isolated belo'w ret. @ 9950' . Isolatedhelo\v ret. @ 9950'. . D- 3 sa. - Isolated belo\v ret. D- 3 Sd. - Isolated below ret. D-4 sa. - Isolated belo\v ret. @ 9750' . @ 9750'. @9950' . == : L___- --~'-- . ¡ ------ _-0_- .-.-- , _ß,f;MA.RKS - ) Sd. -¡ .-' the C-l Sd. r campI I I': 1 c=-=-=-:..l=."..=,=_c.- --~~-~-_..~~ E ctEI V (r~ DEt 11 1AJa .! l :1 ., . ., ==.-.._-~- ---- ~: . ': LAST COlvlPLETIONNO. 01~i.gj.nal ~i .¡ CO!vlPLETION DATE: 8/21/68 PRODUCING INTEHV AL:- Do:) J D_:3 & D-4 Sds. INITIALPHODUCTION: -..--- .,' " ---.-._-~ , ,- ---- -----_ie., .---.- LAST HEC;ULAR PHOD. & DATE: -_..~_J~"vE:?-~~~l ~ . f-mmcf/ d ~Ín October í 971 . .--- ._.._----~' ----- -------lJ..p..J1Q:~__~_6 . 5 mmciLd in, June 197 4 -_.__=~i¡ CUMULATIVE PROOOCTION:__- L2~;'-;:---9-;-991 mmcf thni June 1974 -------:]] UPE.CT 6, i12 mmcf thru June 1974 --------'-.-..- ,"----~-"':,\¡ .---. --_.--- n.,-, 0 C/"...- '---- ---._, .--, ,..., ',,' , f'~ . ìrLl...L.l'Ol" 0 _Ll1't" O-ff 't~"'H '"'"""trv .1:.i'......:AJ l'i .t.t)~ !:~.::::' .0_1l".: -~~-:. ,.., o"o....~-~._~:!~l1 "!'-{~~-_t::'.-q~" ""'1' rL. !It.l. . \ <'? F' D~- ,--=J . _c.,. VI! !L~L' .. --- -- ----_.- .-.--..- ----~' ----- ----.--------------- ." ----.- .----- ._----- ,------ ---------------.-----.--- ---" .------ .--_.---._o.~-_..__._-~- , ¡ /-- - Form D-l001-ß UN IO~\i OIL. CO. OF CÞ\l~IFOF~i~.J iA Rt:.PAIR RI:..COF.ç[) SHEET ß PAGE NO.-----L- T7.."""TA T r.'T""'r-." TT"T-l'T"1 ----- - ___.TTT'.TT 11, .--~ ~ TT'r.1-.TA T "^ r' T""'l'r'T n LEASE_- l"-Ll\l.tLL lJLL'.Jr_UPI 1. W1!;LL l\IUI.'>..LJU ttt:. liirJLu l).~l\nU Uh.ù rlLl..J.1J CO:MPLETION DA'IE: 8/20/74 j-\PPROVEIL - ____JinL-B,,-,--C a]] ell d er "' - _. -_..--- ---_._-- .--,-=.~.. - -=--=--:-=--=--"- -= ......PA.T+ .F..T.p. I. D!:cT_AILS OF OPER!.TIONS. DESCliI.r.JIO1i~~'--li~.sUl, TS ----. PERFORATING RECORD (co~t. . . ) DATE I INTERVAL I ETD REASON PRESENT CONDITION 8/4/7 4 1______------ '- 9. 750' Gmt. Ret. Sqz. perfs below ret. w / 140 ell. it. emt. 8/4/74 I 8,245'-8,25' 8,290' DST #5 Sqz. Upper Tyone w/ 150 sx. G, 6% D-31, I & 1% D-6. Isolated betv;een pkr.s @ 9512i 8/13/741 5,119'-5,12 I 9,7441 \\7S0 Pool 6 C-l Sd. Open for gas productjon. 8/15/74 5,2351_5,26 I 9,744' Production Pool 6 C-l Sd. Open for gas production. 8/15/74 5,170'-5,19q' 9,744' Production Pool 6 C-1 Sd. Open for gas production. 8/15/74 5,1281-5, 13~1 9, 744' Productíon Pool 6 C-1 Sd. Open for gas production. 59- D-1C¡ ." J.. . r'h'3' & '",J. " m Œ ~ œ ~ w œ~ \\ OFC 111f¡1J OtYI$k í'4 f OIL AND GA~ ANCHORAGe .- . '- L- ~._-- - -- --- - ~--' -'UVLT EE' ß'r'". ;. cc;:;!:'. ?c~""ï. Y \"i-; M "-~~-,,~Q.-M--~--- TYPE: CASING HEAD: Shaffer KD 13 5/811 slip on ,-veld X 12H 3::f, CARTN'" HAI,ìr"-v"R. >...>.1. U .,U=-. "'" ,-.(: 13"'0""<7'95/8" l' / 1 1 ,:)DaLer :)/0" A ," sJ..~ps \V seconc.ary sea. CASING SPOOL:- -------- 'T"rYD-~\TC' Hr;1" ~- ... u .!.J1l~:f _J'.":,..AJj; Cd~nìPYO1ì 121: -:;\f v l(u'~, ~~A DrF') ,'1,,/1 ?--?t! h()nn.¡~ <::.t'1cl,1(>(~ outlc"-Lc .........."" JÁ- ~ ~..l. ~ ~ v-- - "'--'- " u u J - '- -.. d '- ,..., - .. .' . - . TUBING HAI'TGER:-.S:.~mcxon 10" Nom, DCB Due] 2 '1/8" EDE X 2 7/8" FUE. TUBING HEAD TOP: C~UT1BYQn 1011 3~d nC:R. l\"f ~ C"T'E. R 'YT .l' T '171i'S' ~d_J"À.>J'" 1... II ..iAJ \!'>-J . Cameron Bloc}: Tree 2 1/2H ---.------'------ --- C""'HlllSr"l?V'íAS (r.-R~'r{1 fl~'OP~. rí)l\]r~T. _i\- 1..... -'- ~J.J ,~'- ,1".. (-' 'ì ~ I () 'I T'l'E ..;'-""'1~n'Î . II ¡..:. ".' ,-;( d " .... '- V I ,. J , ' ) L~.' J -------..-..-------- ¡'c'~;"'"o-i~""',"'~C' - .t¿"c;"""i>. _'-~"'~:-"""\&'~-~-~'¡'Y-ß -'-"" .""..- LEAS E KENAI DEEP UNIT ------.- ----- '. - - ~I;LLI u PAGE No. J ~: lli:. - r;,' ~ ~'. . , . ! t" ~. . t. ~ "-' f ;;:'- .. ' I . ~. -- 3 UNIOt~ OIL CarrANY OF U\LIFORNIA ~[Ll I {[CORD HELL,NO. KDU #2 F I EllJ KENAI GAS FIELD t .- i .- t :'~' k! " k ;" l :, I' ., ~ . '- r .::.. I ' (Footage 0') Bullheaded dwn. tbg. string wI 65#/cu. ft. WO fluid. L: Installed PBV. Began Turnkey Rig move @6:01 am, 7/18/74." 1':- ~ ;., t. '.cr ~ . ~ to .': ~ "::., i ~:;: I . (Footage 0'). Cire. 65# fluid dwn. tbg. & out annulus (tbg. plugged r I wi sd. below - top hyf. pkr.) Installed BPV. Removed x-mas tree. ~; Installed & tested BOPE to UOCO specs. . H (Footage 0') PU on 3 1/211 tbg. & released sgl. hyd. pkr. @ 9818' & i ? 9409'. Unable to Pooh due to swabbing. Worked tbg.' Circ. & I; t condo mud. Unable to stop swabbing from btm. pkr. RU Go-Int'l. ~: RIH to top ofsd. @ 97451. Cut 3 1/2" tbg. @ 9730'. Worked tbg. f ~ r c Tbg. not cut. . RU WL unit & closed "XO" sleeves above + below I top pkr. Circ. thru cut shot @ 9730' while working tbg. '^lell t still swabbing. ~ ~ [;; ~~ .(Footage 0') Unable to part tbg. in cut @ 9730'. Recut 3 1/2" tbg. ~: ~' @ 9735' & Pooh. Laid dwn. 3 1/211 tbg. & accessories. Left 119' of f tbg, & fish in hole, PU as & jars. TlH. Picking up 3 1/2" DP. r - DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS DATE 7/18/74 7/).9/74 7/20/74 7/21/74 7/22/74 7/23/74 ?/?4/74 7/25/74 7/26/74 7/27/74 ETD 10,522'TD 10,477'ETD 10,522'TD 10,477'ETD 10,522'TD 10,477'ETD 10,5221TD 10,477'ETD 10,552'TD 9,735'ETD 10,522'TD 9,782'ETD 10,522'TD 9,449'ETD 10,522'TD 10,461'ETD 10,522'TD 10,461'ETD 10,522'TD 10,4611ETD (Footage 0') Completed Turnkey Rig-up operations @ 6: 00 pm, 7/19/74. Commenced operations @ 6: 01 pm, 7/19/74. Drilled rat- hole. (Footage @ 97821. grapple. 01) TIH w/ as picking up 3 1/2" DP. Found top of fish Worked over fish-unable to hold o_nto fish. Pooh to check ~ f , I I (Footage 0') Pooh. Added extension to as. TIH. Latched onto top of fish @ 9782'. Pulled 5 stds. Pkr. swabbing 100%. Unable . to p'ump by pkr. on annulus w / 3000 psi. Rigged up V'lL unit. Checked top of sd. in fish 10' below as. Ran bailer-unable to bail sd. (Footage 0')' Pooh. Rec. pkr. & tbg. tail. RIH w/ 6" l;it & 7" csg. scraper. Tagged fill @ 99901. CO to 10,461'. (Footage 0') Circ. & condo hole to log. Pooh. Rigged up Go-Intll. & logged Dual Neutron Log 10,3001-9000. Ran CBL-VD Log 10,300'- 9000'. Perf. for WSO test from 10,006'-10,007'. Ran 711 RTTS tool & RBP on 3 1/211 DP. Set RBP @ 10,069'. Tested to 2000 psi-ok. Set RTTS tool @ 10,020'. Tested perfs. from 100281-10,0361 for communications above & 'þelow w/ 1500 psi-possitive press. Held ok. (Footage' 0') Reset RTTS tool @ 9990' & tested perfs. from 10,0061- 10,007' for communications w/ 1500 positive psi-held ok. Reset tool @ 9950' & retested perfs. w/ 1500 positive psi-held ok. Picked up RBP & Pooh. Ran Baker cmt. ret. on WL & set @ 10, 019'DIL. Ran 711 Howco DST tool w / 2000 psi wtr. cushion. Positioned tool @.9950'&flUidV-tubed .prior to settinM'tOOl.' . Pooh &. .£oun~.. DP washout @ 6839'. Comp. Pooh. Chec.. {EoC&IE-+f" ks & press. bombs.. - . '. . . aEC 11 ,~1o! OIVI51~ N \r r 01~ ÞNO OÂ' ~ ANCHO RAa~ ~. , -~-. 'l.,.,J~¿~""'?"-<"'~~"':a..W"':;;~~-'-~~~~--~- --- lIAS E KENAI DEEP UNIT ~~ /'-"'. PAGE No. 4 UNIO['J OIL CarlPNN (f CALIFORNIA '~lELL I <[CORD ~fELL . NO I KDU #2 FIELD KENAI GAS FIELD Dl\TE ETD DETAILS OF OPERATIONS, DESCRIPTIOnS & RESULTS 7/28/74 10,522'TD 10,461'ETD 7/29/74 10,5221TD 10,461'ETD /' 7/30/74 10,522'TD 10,1981ETD 7/31/74 10,522'TD 1O, 19.8'ETD 8/1/74 10,522'TD 10,436'ETD (Footage 0') RIH w/ DST #1 w/ 2000 psi wtr. cushion. Set pkr. @ 995O' to dry test perfs. @ 10,006'-10,0071. Opened tool @ 6: 00 am for 1 hr. Tested dry-no fluid entry. Pooh & laid dwn. . test tool. . IHH - 4442 psi. IFP - 2037 psi. FHH - 4442 psi. Picked up mill & pkr. picker. RIH & milled over Baker cmt. ret. @ 10,018', Pooh & laid dwn. tools. Rec. all of ret. ~ (Footage 0') Completed BO cmt. ret. @ 10,0181. Pooh w/ ret. RU Go-Int. Ran guage ring & junk basket to ETD @ 10,4611. Perf. 4 hpf from 99191-9920'. Set cmt. ret. @ 99501,^lLM. RD Go-Int'l. TIH w/ 711 DST #2 tool. Located on ret. @ 995O' & set tool @ 99151. Opened tool w / 1800 psi wtr. cushion @ 9: 45 am for 1 hr. No fluid entry from perfs. from 99191-99201. Reset DST #2 test tool @ 98791 above prod. perfs, from 9884'-9910', Opened tool @ 12: 47 pm. Had strong blow. Perfs. made wtr. & loaded tbg. Well dead @ 2:30 pm. Closed in tool @ 3:00 pm. Po~h w/ RTTS & found wtr. level @ 272'. Had 40 bbls wtr. entry. Had 5' of sd, fill inside tool. . t t ~. rr ~. i: ~ i r: f t (Footage 0') BO ret. @ 995O' & pushed dwn. hole to 10,198'. Set t isolation ret. @ 9879' between D-3 Zone prod. perfs. from 9884'-99101~ & old DST perfs. from 9854'-9874'. Ran 7" RTTS tool. Displ.. DP w/ 2200 psi gas press. Set RTTS tool @ 9822' & bleed off gas press. Unloaded wtr. in DP & well produced dry gas @ a low rate. (Footage 01) Completed DST testing perfs. from 9854'-9874'. Well producing dry gas & low rate. Rev. out gas-no wtr, entry. Pooh w / RTTS tool. BO cmt. ret. @ 9879' & Pooh w / same. Installed Natco test production seperator. TIH w/ DST tool to production test the D-4 Sd. perfs. from 10,028'-10,036' and from 10,080'-10,0921. . (Footage 0') Completed TIH w / DST tool to prod. test the D-4 Sd. from 10,028'-10,0361 & from 10,0801-10,092'. Set tool @ 10,020' (tail of tool @ 10,041') Charged dry DP w/ 2100 psi. Opened test tool @ 3: 14 am w/ surface shut-in for 10 mins. No inc. on DP press. Opened well on 1/411 choke @ 3: 24 am for 20 mins. IFP. SI well w / 1000 psi on DP @ 3: 45 am for 1 hr. ISIP, Re-opened well @ 3: 56 am for 2 hrs. final flow, Bleed surface press. to 0 psi by 5: 45 am. Left open until 6: 57 am. SI for 2 hrs. FSIP. Pooh, Rec. 21O' of 1 1/2" bbls of rathole fluid above tool. 4 1/2 hrs, rig repairs. (new clutch high & low & new brake blocks), Spotted perf. pill from 10,200'-95001, DST #3 Pressures: IHH - 4559 psi. Open Tool - 2700 psi. IFP - 1192 psi -..30 minso-' ISIP - 2676 psi - 1 hr .-, Re-opened tool - 1192 psi. FFP - 122 psi - 2 brs. FSIP - 2338 psi - 2 hrs, rID Œ a: fE n.\VI fE -t~ IN DEC 1 t 1974 [ ~f\lrz,\- t~ ~ P OIL AND G;.., Af\!CHORAc;e . ~. /~ "~ ~ "~~.:"~",~~~:---,-,,:-c=~-~.~=--~ LEAS E KENAI DEEP UNIT .-". UNlor'J OIL CIT'1PANY (f CALIFORNIA '\'fLL I {[CO~ill ~fLL NO. KDU #2 "'. ..-~. - ~ -. PAGE No. 5 FlEW KENAI GAS FIELD I DATE ETD i' 8/2/74 10,522'TD 10,436'ETD /' 8/3/74 10,522'TD 9, 750 'ETD 8/4/74 10,522'TD 8,290 'ETD 8/5/74 10,522'TD 8,290'ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS (Footage 0') Mixed 68.8# Dril-S pill & spotted across perfed interval 10,200':-9500' (35 bbls). RU Go-Int'l & reperI. D-4 Sds. from 10,026'-10,038' & from 10,0761-10,094' w/ 411 csg. gun @ 4 hpI. Ran 7" Howco DST tool #4. Set tool @ 10,018' (tail @ 10,039') Charged DP w/ 2175 psi gas press. Opened tool @ 10: 57 am w / surface valve closed. No press. inc. on surface. Opened surface valve @ 11: 00 am to flare. SI well @ 11: 30 am (1st flow period) w/ 200 psi (IS1P). Re-opened well @ 12: 32 pm for final press. build-up. Pulled tester loose @ 7: 30 pm. Pooh. Rec. 420' or 3. 1 bbls of fluid (wtr.) in DP. DST #3 Pressures: IHH - 4540 psi. Opened Tool - 2674 psi. IFP - 344 psi - 30 mins. ISIP - 2282 psi -- 1 hr. Re-opened tool - 148 psi. FFP - 221 psi - 3 hrs. FSIP - 2159 psi - 4 hrs., FHH - 4540 psi. I t! Þ i , I- È ~ . Ii.- é'. t , , k l I. ./ (Footage 0') RU Schlumberger. Ran CNL-Density Log from 10,3001- 4300' . Ran CBL-VD Log from 10,3001-5790'. Set Baker Model "KI1 cmt. r'et. on WL @ 99501. Set Baker :Model "K" cmt. ret. on WL @ 9750'. ' (isolate & sqz. D-3 & D-4 5ds.) Ran ret. stinger on 3 1/211 DP to 9750'. (Footage 0') Set into cmt. rete @ 9750'. Broke dwn. fm. @ 2200 psi. PI @ 5 cfm. ~Æixed 150 sx. Class "GII cmt. w/ .6% D-31, .5% D-19 & 1% D-36. Initial PI w/ cmt. 8 cfm @ 1800 psi. Final PI .5 cfm @ 4000 psi. (sq z. 140 cfm cmt.) Rev. out 32 cf cmt. Pooh. RU Schlumberger. Ran Baker Model ilK" cmt. ret. & set @ 8290'. Perf. Upper Tyonek Sds. from 82451-8255' w/ 411 csg. gun @ 4 hpf for DST #5. Ran 7" DST #5. Set tool @ 8217' & charged w/ 2175 psi gas press. Opened tool @ 3: 12 pm w / surface closed pI"ess. inc. on surface to 2425 psi. Opened surface @ 3: 20 pm. Flowed well to 4: 25 pm w / dee. in press. to 3000 psi for 1st flow period. 51 well @ 4: 25 pm for ISIP. Re-opened tool @ 6: 15 pm for 2nd flow period. Flowed well 2 1/2 hrs. @ 1.68 mmef/ d w / 300 psi surface p~ess. (no wtr. entry) SI well @ 8: 35 pm for FS1P. (Footage 01) Rev. circ. gas cut mud out of DP & annulus thru cire. sub w / DST tool SI for final SI period. Leveled fluid wt. out @ 69#/cu. ft. Released tool @ 6: 30 am. Press. inc. immediat- ely to 100 psi on csg. & DP. Raised fluid wt. to 71#/ cu. ft. & rev. out gas cut fluid. Press. inc. to 400 psi on DP & csg. Inc. fluid \vt. to 73#/cu. ft. Displ. csg. & annulus. Bullheaded 73# fluid from circ. sub @ 8186' to perfs. @ 8245' to 8255'. Circ. 73# fluid up DP holding 300 psi back press. Bleed off DP & annulus. Opened hyd. & circ. around 73# fluid. [õ) Œ rœ ~ ü.W, Œ 1(' . ~ DE--C 1 ' , "'.! L ... 1 19 ,~: .--,Ivts",. I~ ~ F OIL Â~D \... k- .. p' Al\\CHORAOF. / .-~/'-c~'éc'~~:"-'F"c"-<~~=""'-~-c~~'~-'-'--'-' ~ lIAS E KENAI DEEP UNIT /--, /'-. PAGE No. 6 UNIOI'J OIL Ca1PANY OF CALIFORNIA . ~~'ELL I {ECORD HELL NO. #KDU #2 FIELD KENAI GAS FIELD DATE Em DETAILS OF OPERATIONS, DESCRIPTIons & RESULTS 8/6/74 10,522'TD 8,290'ETD 8/7/74 10,522'TD 8, 1851ETD ~ 8/8/74 10,522'TD 8,290'ETD 8/9/74 10,5221TD 9,744'ETD 8/10/74 10) 522'TD 9,7441ETD f -- DST #5 Pressures: IHHP - 3386 psi. IFP - 2601 psi. FFP - 467 psi. ISIP - 3950 psi. IFP - 786 psi. FFP - 516 psi. SSIP - 4049 psi. (Footage 01) Compo Pooh w/ DST #5. TIH w/ 6" bit & 7'1 esg. ~~ scraper. Tagged bridge @ 8201' above perfs. from 8245' to 8255'. { Picked up to 81311. Cire. & condo fluid to 73#/eu. ft. Pooh. b Ran 7" RTTS tool wi 60' of 2 3/8" tbg. tail. Washed out fill in !: hole from 8201'-8272'. Set RTTS tool @ 81341, tail @ 8198'. Rigged [: up sqz. manifold. Ci~C' & cond. gas cut fluid to 73#/cu. it. ¡l (Footage 0 I) Comp. elre. out gas cut. mud. RTTS tool set @ é ¡: 8134' & tbg. tail @ 8198'. Ree. sd. & salt from rathole below perfs. ~ ¡: on btms. up. Pumped into perfs from 8245' to 8255'. (2 cu. ft. / t min. @ 2900 psi. Inc. press. to 3200 psi & frae. form. Pumped in t @ 8 cu. ft. /min @ 2900 psi. Opened perfs. to surface thru DP . No t flow or press . inc. in 2 hrs.' Ran WL. Checked tb g. tail @ 81961. l . fill @ 82731. No indication of gas entry or flow. Released RTTS 1 I tool. Pooh. Set Howeo EZSV emt. ret. on \^lL @ 8185'. TIH w / ret. ~ stinger on DP. Stabbed into ret. Break dwn. of 10 cu. ft. /min. @ ¡ 2900 psi. Pulled out of ret. Pumped 56 cu. ft. of wtr. ahead & r behind emt. Pumped 150 sx. w/ "G" w/ .6% D-31, .5% D-19 & 1% . by wt. of WIT. of D-6. Pumped 56 cu. ft. of salt wtr. Closed tool. Displ. w / 240 ell. ft. Pump rate of 5 cu. ft. /min @ 3600 psi final 51 standing press. of 3250 psi. Pulled out of ret. (Footage 0.1) Pulled ret. stinger to 8155' & rev. out 4 cu. ft. of emt. Pooh., RU WL unit. Ran Go-Int'l CBL-VD Log from 6000'- 40001. TIH w/ 5 7/8" bit. Drlg. emt. ret. @ 8185'. Drlg. firm emt. to 82571 (2' belo\v perfs. from 8245'-82551). Washed d-'ln. to top of ret. @ 8290'. Cire. btms. up. (Footage 0') Cire. 2' fill on top ret @ 8290'. Unable to stab into ret. w/ stinger. BO ret. & pushed to 9744'DPM. Pooh. Ran 6" (used) bit. & scraper to 97441ETD. Ran 7" RBP & 7" RTTS tool fo~ Hydroxy-Aluminum sd. treatment. (Footage 0') Set. 7" RBP @ 9615'. Set RTTS @ 95401. Treated Lo\ver D-2 Zone perfs. from 9558'-9588'DIL w/ 1000 gallons 5% HCL, 2800 gallons 5% KCL, 6300 gallons Hydroxy-Aluminum, 3800 gallons 5% KCL. Initial PI rate 9.7 gpm @ 2300 psi. Final PI rate 9.7 gpm @ 2700 psi. - \¥1 Œ~~ Œ ~ ~ ~ rID -. ", OEC 1 \ \~;~\ D'V\S\~ h .~ \;i O\L -.~t:} OÂ~ At~\CHO RAa~ ~. LEAS E KENAI DEEP UNIT U~ION OIL ca.rIPANY If U\LH-UI<rUJ\ .- r \,[LL I {[CORD I æ 11 ~ -t ~ PAGE r.!o. 7 \'fLL NO. FlEW _KENAI GAS FIELD KDU #2 DATE DETAILS OF OPERATIONS, DESCRIPTIons & RESULTS 8/11/74 8/12/74 ------ 8/13/74 8/14/74 8/15/74 ETD 10,522'TD 9,7441ETD 10,522'TD 9,744'ETD 10,522'TD 9, 744JETD 10,522'TD 9,7441ETD 10,522'TD 9,744'ETD (Footage 0') Completed Hydroxy-Aluminum treatment on Lower D-2 Zone perfs. from 95581-95881. Reset RBP @ 9546'. RTTS @ 9526'. PI 1 cfm@ 3000 psi. Reset RBP @ 9540', RTTS @ 9535' . Reset RTTS @ 9490'. Held 3000 psi - ok, Pulled RTTS to 9262'. Ran strip GR-Collar Log thru DP from 95431-91501. DP tools checked 3' high to WLM. Set RTTS @ 9257' & tested 4000 psi on 7" ok, Reset RBP @ 9624' & RTTS @ 9609'-held 4000 psi. Reset RTTS @ 95991-4000 psi - ok, 9589'-4000 psi-ok. 95791-PI & circ. round tool. Reset RBP @ 9556' & RTTS @ 9546'. PI 1 cfm @ 2200 psi. Reset RBP @ 9544'. RTTS @ 9536'-held 4000 psi ok. (slow bleed). Above testing determined D- 2 Zone perfs. + 9546' - +9580'. "". r'T ~. ~, ~. i' r' È. ~. f t ~ V; ~ '" ~ f; r f .. ~'. (Footage 0') Completed TIH wi RBP & 711 RTTS tool. Unable to ~ ,. set & test RBP. Pooh. Picked up new RBP & 711 RTTS. Unable to ~: set & test RBP. 'Pooh. Picked up new 7" RBP & 71: R TTS tool. i TIH to top of 711 liner. Set RBP & tested to 3900 psj. Reset @ r: 9538' & RTTS @ 9530' & tested RBP to 3900 psi-ok. Reset RTTS @ 9480' to treat the D-2 Zone Upper perfs. from 9510'-95221. Broke dwn. perfs. wi 2650 psi. PI 1 cfm. (Footage 0') Completed pumping Hydroxy-Aluminum on Upper D-2 perfs. from' 95101-95221 wi the following: 500 gal. HCL 5%, 1000 gal. KCL 5%, 2500 gal. Hydroxy-Aluminum, 1500 gal. KCL 5%. Pooh wi RBP & RTTS tool. RU Go-Intll & perf. above Pool 6 C-1 Sd. from 5119' to 51201 for WSO test. TIH wi 9 5/811 RBP & RTTS tool. Set RBP @ 5160'. Set RTTS @ 5090' wi dry DP & press. DP wi 2000 psi gas. (gas kicked on annulus while setting RTTS tool). Pulled RTTS tool loose & rev. out gas cut mud in annulus & DP. ¡ ! t f I [ r f , ,. (Footage 0') Rev. out gas cut mud wi RTTS tool @ 5090' & leveled wt. off @ 74#/cu. it. Unable to set RTTS tool to test VISa perfs. from 51191-51201. Reset RBP @ 5000' above perfs. Pooh. Found 3 loose connections in DP string. Reran RTTS tool.. PU RBP & reset @ 51831. Set RTTS @ 5150' & tested 3000 psi -ok. Reset RTTS tool @ 5085'. Displ. DP wi 2100 psi gas press. Opened tool wi 2300 psi. HH on perfs. @ 51191 to 5120' for WSO test. Flowed '\vell & tested perfs. @ 51191 to 5120' @ 2 mmcf/d rate wi 1100 psi ~urface press. & no wtr. cut. SI well @ 1400 psi. (Footage 01) Completed rev. out gas cut mud. Pooh wi RTTS tool. Perf. Pool 6 C-1 Sds. from 5235'-52651, 5170'-5190' & from 5128'- 51381. ,Made bit & scraper run to top of 7" liner @ 5821'. Ran 9 5/811 RBP & RTTS too1. Set RBP @ 53001. All perfs communicat- ed. Set RTTS tool @ 5090' for Hydroxy-Aluminum treatment of C-l Sds. ~lf~ ~ ~t\ID~~D GEC 1 ,g7'¡ r D\V\SIC N. \.¡ f n. AMD GAS ANCHO AGe. (Footage 01) Completed Hydroxy-Aluminum treatment on Pool 6 C-1 Sd. perfs. from 5235'-5265' & from 5170'-5190' & from 5128'- 51381. Tested '^lSO perfs. from 5119'-5120'. Pumped 2250 gal. of 5% HCL & 5300 gal. 5% KCL & 12,600 gal. Hydroxy-Aluminum & 7550 gal. of 5% KCL. (all perfs. were treated simultaneously together w / above total treatment due to con1n1unications between perfed intervals.) Pooh wi RTTS & RBP. Set RBP @ 1000'. ., - ,. Removed tbg. head shaffer 12" 3M X 10" 5M & replaced w/ Cameron ~-~'£""""_.;;'é.':'~,"."';""="""~~~C......--~-~~~~-=~-:-~"--=-:C~=.-.- -- lEAS E KENAI DEEP UNIT r-, ~ 8 t- f~ r,. ~ t-.. ~. l~~, ~- ~'- ~, ; r- f ~~ r:- i". ~: I:' t'i t', ~- v-. , f f: f ¡, I,' !" . . p- i,: í i - PAGE No. UNIon OIL CIT'1PANY (f- CALIFORNIA h£Ll I {[CORD t'.:. -, t"O p -.. ~ . KDU #2 KENAI GAS FIELD F I Ell) IJ.L\ TE ' ETD DETAILS OF OPERATIONS, DESCRIPTIons & RESULTS 8/17/74 10,522'TD 9,7441ETD 8/18/74 10,522'TD 9,744'ETD 8/19/74 10,522'TD 9,744'ETD ------ 8/20/74 10,522'TD 9, 744'ETD 12" 31v1 X 10" 3M. (Footage 0') T èsted BOPE under RBP. Pooh. Laid Pooh. Laid Completed changing out tbg. head & installing BOPE. to 3000 psi - ok. Retrieved RBP @ 1000'. Had gas TIH to top of liner @ 58211 & circ. out gas cut mud. dwn. RBP. TIH w/ OEDP to 96801. Circ. btms. up. dwn. 3 1/2" DP. r:, ,. rCè r. í- ~' I. t l (Footage 0') Ran dual 2 7/8" tbg. string as programed. ~; Spaced out & landed tbg. Tested Baker 7" X 4" perm. pkr. @ ! h 9500' w/ 800 psi. Ran & set "N" plug in LS, "N" nipple @ L 9521'. Set Brown 9 5/8" X 2 7/8" RH-l pkr. Opened "XO" ¡ sleeve @ 9420' & tested pkr. w / 1000 psi. Closed "xo" sleeve & f retrieved "N" plug. Ran & set "N" plug in SS, "N" nipple @ 5110'. f ¡ Set Brown 9 5/8" X 3 1/2" X 3, 1/2" RH-2 pkr. @ 5098'. Tested ~ pkr. to 1000 psi-ok. 1 t . (Footage 01) Completed laying dwn 3 1/2" DP, collars & Kelly. RU Go-Int'l. Ran JB & guage ring to 9600'. Ran Baker 7" X 4" perm. pkr. & set @ 95001. Changed out pipe rams to 2 7/8". RU to run 2 7/8" tbg. (Footage 0') Installed BPV. Removed BOPE ~ Installed x-mas tree & tested to 3000 psi. RU slick line & opened IIXO" sleeve @ 55361. Displ. salt wtr. wi visco N-55 pkr. fluid. Closed "XO" sleeve. Opened IIXO" sleeve @ 5051' & displ. annulus w/ .5% N-55 visco pkr. fluid. Closed sleeve @ 5061'. Opened "XO" sleeve @ 5536' & displ. tbg. w/ field gas. RELEASED RIG @ 6: 00 2m, 8/20/74. f5) Œ f!3 IE 0 WI Œ ~- lr~ DEC 1 t 197" L C:.IVf5t( í", i~ OIL ÂNþ GAw A¡\(:HORAGE ~. /, .---", UNIon OIL CarlPr~f{ OF CALIFORNI{\ v[LL I {[CORD LEAS E KENAI DEEP UNIT HELL NO. KDU #2 ~ ~, ..-_. P^GE No. 9 [ " ¥. \' F I ElJ1 KENAI GAS FIELD LENGTH 0.55 1.20 10.00 16.24 ----- 1.00 1.00 61.78 3.12 3823.08 8.71 8.06 2.67 62.56 3.12 - 186.06 12.07 20.00 31.72 50.00 30.72 40.00 10.00 20.00 31.73 8.03 31.70 3.12 5038.97 5.12 DETAILS OF OPERATIONS, DESCRIPTIons & RESULTS - lê.'.:.",~,' ,. , >, -j. BOTTOM 9539.63 9539.08 9537.88 9527.88 9511.64 9511.64 9510.64 9509.64 9447.86 9444.74 5621.66 5612.95 5604.89 5602.22 5539.66 5536.54 5350.48 5338.41 5318.41 5286.69 5236.69 5205.97 5165.97 5155.97 5135.97 5104.24 5096.21 5064.51 5061.39 22.42 17.30 16.65 15.70 Þ' DATE ETD l .- TOP ~~.'.: K t , ¡,~ ~ ~. &, r ø t: '-,' f. f ¡ f.. ~ r f ". ¡ I, " £ l , ¡ .65 .95 15.70 ~. ff (fI) Ii ß WIEr :. ~"" . 1 ~o~c lJIg i i DEC 11 1\ l:~, ~t\ltSk. N OF OIL ANCHORAG ' TUBING DETAIL LONG STRI NG JTS. DESCRIPTION 2 Mule Shoe Otis "N" Nipple ID-2. 205, OD-3.25 2 7/8" Seal Lock Pup Baker Seals Baker Model "D" Pkr. Up off pkr. Baker Locator Sub 2 7/811 Seal Lock Tbg. Otis "XO" Sleeve ID-2,313, OD-3.75 2 7/8", Seal Lock Tbg. BOT HI - RSP Pkr. 2 7/8" Seal Lock Pup BOT Seal Lock Pull Safety Jt. 50,000# ,2 7/811 Seal Lock Tbg. Otis "XOII Sleeve ID-2.313, OD-3.75 2 7/811 Seal Lock Tbg. 2-2 7/8" Seal Lock Pups 8.021, .4.051 2.68"0D Blast Jt. 2 7/8" Seal ~ock Tbg. 3-3.68"OD Blast Jts. 2 7/811 Seal Lock Tbg. 2-3.68"OD Blast Jts. 2 7/8" Seal Lock Pup 3.68110D Blast Jts. 2 7/8" Seal Lock Tbg. BOT H - 2 D,ual Pkr. 2 7/811 Seal Lock Tbg. Otis "XO 11 Sleeve ID-2. 313, OD-3.75' 2 7/811 Seal Lock Tbg. 2-2 7/8" Seal Lock Pups, 3.05', , 2.071 2 7/8" EUE 8rd X 2 7/8" Seal Lock DBL Pin. Hgr, Elevation 123 ----- 2 6 1 1 1 1 161 298 Jts. Total Jts. of 2 7/8" 9539.08 9537.88 9527.88 9511.64 9511.64 9510.64 9509.64 9447.86 9444.74 5621.66 5612.95 5604.89 5602.22 5539.66 I I l- t r L ¡j ~. 5536.54 5350.48 5338.41 5318.41 5286.69 5236.69 5205.97 5165.97 5155.97 5135.97 5104.24 5096.21 5064.51 5061.39 22.42 17.30 16.65 15.70 -0- ~~._--- ----. .. . -~ P^GE rJo. - 10 E, lit; ¿=- .. UNIOfJ OIL Ca~r~)NN OF CALIFORNIA .HELL HECORD ;;; 'N' JTS. I DESCRIPTION LENGTH BOTTOM TOP Otis IINII Nipple, ID-2. 205, OD-3. 25 1.20 5113.48 5112.28 2-2 7/8" Seal Lock Pups, 4.01', 4.03'. 8.04 5112.28 5104.24 BOT H-2 Pkr. 8.03 5104.24 5096.21 2 I 2 7/811 Seal Lock Tbg. 63.46 5096.21 5032.75 Otis "XO" Sleeve, ID-2.313, OD-3. 75 3.12 5032.75 . 5029.63 160 ' 2 7/8" Seal Lock Tbg. 5008.62 5029.63 21.01 2-2 7/811 Seal Lock Pups, 1.07', 3.04' 4.11 21.01 16.90 ~ I .' I 2 7/8" .EUE 8rd X 2 7/8" Seal Lock DBL Pin .25 16.90 16.65 Hgr. .95 16.65 15.70 Elevation 15.70 15.70 -0- 162 J ts. I Total Jts. of 2 7/811 Seal Lock Tbg. ~ ~- ~ (: I.~.~.;..' ~. I I f ~. ~ ~. þ ~ ~: I: ~:., f. t r ~ .. t. . ! ~ l ¡ [£AS E KENAI DEEP UNIT hELL NO t KDU #2 FlEW KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCHIPTIOilS & RESULTS TUBING DETAIL SHORT STRING I' ,. \ . ~. œ (~œ n ~/ Œ L~' . ...DEC11 ,~ . ~ ~ it~K~ N OF OIL ANCHORAù " . I --.r. .. (" t "- ~I J, Formation Testing Service Report I DIR ! .' I C I".:::() j)'" I "~. ~ - ~. _. - , c. . ,'-.:(-~ ../J / l.l-- I i [1,jG I , . -,L- , ? "~,r-- t" - I "v. . /L_. ') r"~ . --'-- ) I ,-, ,"-I"ll I 4 U.;G 1'0. '. , I I [. rNG - J C;:()L -¡¿ - I ')'-,.., ""L 1- , ,'- -,;> ,\,1 r- I 3 C t:Ol r- oO 'REV r-- --,.of Df\/\Ffl--- - r SEC ,',~-I ...- ( .~';~!F::;( .-..,--..--- f'iLC:; m' \:-::Jr" .~' IT;::J Ü W. Œ- :-,;-, " " I. ' U ' \ .. '. \ D),:,~':i.'-'.'.Ji,' -:r'l'" _, , l. , \\ .1 . ¡ I I I 'I u~ '...,J , -,' L,..J . ~ ~) S~p 23 i9]'4 r'p,".-,'1 '" \, r.;I i.~.F) r:: \1" _..".--,.,1"""" ..,1,._"",- ...,,¡-..) ,~\..:..-'i.~¡":f)...r';-: "'.1 . - I : '.." ..r ;.. HAll/HI/R10N SERVICES DUNCAN, OKLAHOMA FLUID DATA Ticket Number 599128 8-5-74 HOOK WALL SAMPLE Dote - Sampler Pressure Recovery: Cu. Ft. Gas cc. Oil cc. Water cc. Mud Tot. Liquid cc. P.S.I.G. at Surface Kind of Job Halliburton District ANCHORAGE BOATMAN Witness HESS Tester g~~J/~~tor KENAI DRILLING COMPANY EQUIPMENT & HOLE NM s DATA Gravity Gas/Oil Ratio ° API @ OF. cu. ft./bbl. CHLORIDE CONTENT - Formation Tested Elevation ~ Ft. Z Ft. I 92.6 Kelly Bushing Holes @ 82451 - 82551 Kelly Bushing PBD 8290. 9 5/811 - 711 -" -" Ft. :E: RESISTIVITY Recovery Water Recovery Mud Recovery Mud Filtrate -@ of. @_OF. - @ - of. @_oF. @_oF. Net Productive Interval ppm All Depths Measured From ppm Total Depth ppm Main Hole/Casing Size ppm Drill Collar length ppm Drill Pipe Length Packer Depth(s) cp Depth Tester Valve Ft. Ft. J.D. J.D. - - Mud Pit Sample Mud Pit Sample Filtrate 2.76411 82001 82171 81951 Mud Weight TYPE vis Surface Choke AMOUNT GAS 21751 Depth Back Ft. Pres. Valve Bottom Choke 5/811 hI! & kll 4 2 81891 Cushion Recovered Feet of :>!! ~ 8 õ: P "T1 ... 0 3 ~ lit ..... 111 ... Recovered Feet of Recovered Feet of Recovered < Ã c T' <" Z 111 :;þ I'-t Feet of Recovered Feet of Remarks C = READ AT THE END OF 129.6 MINUTES WHEN CHART TIME EXPIRED... Q = QUESTIONABLE. SEE PRODUCTION TEST DATA SHEET FOR REMAINDER OF THE REMARKS... ;A CHARTS INDICATE POSSIBLE LEAKAGE DURING THE INITIAL CLOSED IN PRESS~ Gauge No. 338L Gouge No. ¿8!:>/ Gauge No. JJtS I UKt. ;:: DCDth: 82001 Ft. Deoth: 820.4 1 Ft. DeDth: 82291 Ft. TIME OJ ¿4 Hour Clock I ¿ Hour Clock ¿4 Hour Clock Tool 8-4- 74 A.M. ~ Est. of. Blanked Off NO Blanked Off NO Blanked Off Y t~ OpeneJ: 12 P.M. ~ K/_~K1 ld OpenerS-5-74 AM. :I: Actual 103 OF. Pressures Pressures Pressures Bypass 6: 30 P.M. Field Office Field Office Field Office Reported Computed 3352 ~BOQ 3338 ]3R8Q 3386 -~_~Y_'H~ Minutes Minutes- 2591 2579 2580 2584 2601 2591 --- --- ~ 0 459 461 469 460 467 474 95 95 it 3969 3955 3926 3961 3950 3963 88 91 773 785 766 804 786 811 ------ 483 498 494 493 516 506 140 143 :;þ 4040 4057 - 3951C 4049 4064 955 589 ç (/) --- ~ TEMPERATURE Initial Hydrostatic Initial "E] Flow ü: Qj Final 0. Closed in ""0 Initial g ,2 Flow u'" Final Q)QJ V> 0. Closed in Initial "E-g Flow :c ï: Final ~~ Closed in Final Hydrostatic - - - - - - - - --- "°11'" "'-~IIINT!:D IN U.S.A. FORMATION TEST DATA r- .> LITTLE" UII74 ~'" ./71 v>r t1)1D not) " Q.. ~r t: 0 un . C ,:!: ;:00 :J:J rp "-J I rA t1) ~O ID ~c:: 3 ID ~N Z ? ~ - :J¡ Q) ..... Z ? ø :;þ (/) " I'-t T' r - 0 00 N --' -i"-J 111 1ft ..... ID Q. I :J ;00 < N c 1...0 -0 I- f) 0 C :I -+ '< c:: Z ........ a ::z 0 ........ ï r n ~ 0 ~ 3: 0 \J ~ :Þ :J :z ~ -< ...... f) 0 (:) 3 " "0 C :I n '< :Þ ~ r- 3 ........ CD " a ;0 :::2: ........ :Þ V>r FLUID SAMPLE DATA Ticket <;)1\) 8-5-74 599128 /"olD Date Number '1 ~ "'r Sampler Pressure P.S.J.G. at Surface '" 0 Kind Halliburton "n HOOK WALL ANCHORAGE . a Recovery: Cu. Ft. Gas of Job District I::!'. ;00 :3:3 ce. Oil '!J ce. Water Tester BOATMAN Witness HESS ce. Mud Drilling Tot. Liquid ce. Contractor KENAI DRILLING COMPANY NM S '-oJ Gravity ° API @ OF. EQUIPMENT & Hal E DATA I Gas/Oil Ratio cu. ft./bbl. Formation Tested .þ. :z RESISTIVITY CHLORIDE Elevation Ft. I CONTENT Net Productive Interval Ft. -" Recovery Water @_oF. ppm -" All Depths Measured From ~ Recovery Mud -@ OF. ppm Total Depth Ft. Recovery Mud Filtrate @_oF. ppm Main Hole/Casing Size Mud Pit Sample @ of. ppm Drill Collar length J.D. Mud Pit Sample Filtrate @ of. ppm Drill Pipe Length J.D. Packer DepthCs) Ft. Mud Weight vis cp Depth Tester Valve Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke Choke - Recovered Feet of >::!! ~ ...~ I\) 2ö: p Recovered Feet of " ., 0 3 ^ ... Jï1 Recovered Feet of !II :z III ... :Þ I\) ., ...... < Recovered Feet of Q. G) < :Þ I\) c.n Recovered Feet of "T1 ...... Jï1 Remarks ï a - CC;:' READ AT THE END OF 132.9 MINUTES WHEN CHART TIME 1- t"p lKtU. .. () 0 Q QUESTIONABLE.. c = :3 ... '< FOURTH GAUGE TEMPERATURE Gauge No. 2Bt>b Gauge No. Gauge No. TIME ^ 8233' Jï1 Depth: Ft. Depth: Ft. Depth: Ft. :z 12 Hour Clock Hour Clock Hour Clock Tool AM. :Þ ...... Est. of. Blanked Off ytS Blanked Off Blanked Off Opened P.M. OJ Opened AM. a ;0 Actua I of. Pressures Pressures Pressures Bypass P.M. a c:: Field Office Field Office Field Office Reported Computed G) :J: Initial Hydrostatic 3359 33YIQ Minutes Minutes - Initial 2578 /.,Kh V> ~] Flow ... ~4 0 Final 462 ... .-'" !II u.4I/ Q. Closed in 971 3971 "0-0 Initial 779 822 - - g.Q Flow Final 487 504 u'" :Þ 41/0.1 VlQ. Closed in 3983CC ï - :Þ Initial - - c.n ~] Flow Final ~ .J:'" f-æ Closed in Final Hydrostatic CHART TIME EXPIR ED.. - - rORM III-I'RINTED IN U.I.A. FOR-MATI ON TEST DATA LITTLII'I "'74 aM '/13 :;'" 0 ~O Z' dc:: 3 . II> ~ ~N Z ? ... I\) ~(j') Z ? 0:> N --' '-J ... II> ~ I I\) ~o:> :?N I\) lO < a 0 c z ........ a z a ........ r r n C1) a fJ ::s.: II> -a 0 ):::0 ~ z ~ -< ~ Qa 3 "T1 " 0 n ~ ):::0 zr 0 ....... 3 II II> a ;;a :z ...... :Þ r-:- Casing perfs. 8245 I - 8255 I Bottom choke 5/811 Surf. temp of Ticket No. 599128 Gas gravity Oil gravity GOR Spec, gravity Chlorides-- ppm Res. @ of Date 8-4-74 Choke Surface G:Js liquid .. Time a.m. Size Pressure Rote Rate Remarks p.m. psi MCF BPD 3: 12 2175# Opened tool - head closed.. . 3:20 kll 2425 Opened head. 4 3:25 II 2150 3:30 II 1950 3:35 " 1800 3:40 II 1700 3:45 " 1650 3:50 II 1600 3:55 II 1550 Opened to ~II choke. 4: 1 0 3--.,11 400 4:25 II 300 4.30 II 300 1.45 APPROX. II 300 4.47 Closed in for a 91 minute first closed in pressure. . 6: 15 II 300 Tool opened for 143 minute second flo~ 6: 18 II 425 Opened at the surface. 6:25 II 425 6:30 II 350 6:35 II 330 6:45 II 325 6:50 II 325 7:00 II 325 7: 15 II 325 7:30 II 325 7:45 II 325 .,' 8:00 " 325 ,.nINTED IN U,S,A. PRODUCTION TEST DATA LITTLa' . 5- '...,,- ". "--.:'. .. "', ",-:'...'" Casing perfs. Bottom choke Surf. temp OF Ticket No. 599128 Gas gravity Oil gravity GOR Spec. gravity Chloridec; ppm Res. @ of Date Choke Surface Gas liquid Time a.m. Size Pressure Rate Rate Remarks PAGE # 2 p.m. psi MCF BPD 8: 15 kit 325 1 .6 2 8:30 II 325 1 .6 8:35 PM 18 325 Closed in and reversing.. 8-5-74 6:30 Pulled loose - conditioned the mud. 0' 0 , ,./IINTED IN U.a.A. PRODUCTION TEST DATA LITTLE' . .::.' .. \ Gauge No. 3382 Depth 8200' Clock No. 8739 24 hour Ticket 599128 No. First II First I Second Second II Third Third Flow Period Closed In Pressure Flow Period Closed In Pressure Flow Period Closed In Pressure PSIG I PSIG Time Def!.1 I Time Defl. Log t + () PSIG Time Def!. PSIG Time Def!. Log t + () I Time Def!. PSIG Time Deft Log t + () P~'G .000" Temp. .000" Temp. .000" Temp. .000" Temp. .000" Temp. .000" Temp. Corr. () Corr. Corr. () Corr. Corr. () Corr. 0 .000 2579 .000 461 .000 785 .000 498 1 .01641 2762* .304 3955 .0761 531** . 1426 3867** 2 .0657 2231 . 1423 507 .2719 3919 3 . 11 50 1916 .2085 502 .4012 3952 4 (. 1460 1818C .2747 498 .5305 3974 5 . 1643 1012 .3409 502 .6598 3993 6 .2136 510 .4071 495 . 7891 4007 7 .26291 464 .4730 498 .9184 4017 .3120 461 ' 1.0477 4024 8 9 1.1770 4031 10 I.-.mh-O{ 4038 11 I 1.ll.'o{~6 4043 12 ~ 4047 13 . 4052 14 . 5 4054 15 I . 5 0 40~7 Gauge No. ?R~. Depth R?O4' Clock No. ---~ hour 12 bli'Y 01 .000 2584 .000 460 .000 804 .000 493 1 .0337 2721* .621 3961 . 1531 530** .2892 3862** 2 . 1 348 2262 .2862 507 .5515 3919 3 .2359 1929 .4193 502 L 8110 3951CT ) 4 (.30601 1812C 5524 495 .8138 CHART 5 .3370 1122 &::oc::.c::. 505 1 .0761 TIME 6 43811 512 8186 495 1.3384 EXPIRE .... 7 465 9520 493 1 .6007 I "-~Yl' 8 hl1nn 460 1 . 8630 - 9 2. 1253 - 10 2.3876 - 1 1 I 2.6499 - 12 2.9122 - 13 3.1745 - 14 3 4368 - 15 I ~ fiqql - Reading Interval 15 I I 20 . 3.9620 - Minutes REMARKS: 39 C - CHOKE CHANGE. * INTERVAL - 5 MINU1ES. ** INTERVAL - 23 MINUTES. xx"/(; IN tKVAL - 4j MINUlt~. CTE = READ AT THE END OF 129.6 MINUTES WHEN CHART TIME EXPIRED... PRINTED IN U.S.A. SPECIAL PRESSURE DATA LITTLE'S .. \ .J j 'I ! ¡ of :4 II', 'J Gauge No. First Flow Period Time Defl.l PSIG 000" Temp. 0 Corr. a .000 I 259i 1 .0 6 2 .0659 3 . 11 53 4 .15101 5 . 1 647 6 .2141 7 .2635 8 . 3130 9 10 11 12 13 14 15 Reading I ntervol 2586 2745* 2151 1930 ] 82lC 1107 530 477 474 15 3381 II First Closed In Pressure I Time Defl. I Log t + () .000" () .000 :3UT 2856 .000 .596 Depth 8229' Clock No. 8420 1- - Second Second 1 Flow Period I Closed In Pressure PSIG .1" Time Defl. I PSIG Time Defl. L t + () I PSIG Temp. 000" Temp. 000" ag Temp. Corr.' Corr.' () Corr. 474 -3963 Depth 474 3971 .000 .0758 .1417 .2076 .2735 .3394 .4053 .4710 8233' ..QlliL . 1491 .2788 .4085 -- .5382 .6679 .7976 .9270 811 I. 000 5~8** _.!J.il~ 518 .2704 511 .3990 509 .5276 516~562- 504 .7848 506 I. 91 34 1 . 0420 1.1706 j_u._- 1.2992 1 .4278 1.5564 1 .6850 1.8136 11.9420 822 543** 521 513 509 518 509 504 Clock No. .000 ?80? 5:i43 - 7884 ( .8660 1 .0425 1.2966 1 .5507 1.8048 2.0589 2.3130 2.5671 2.8212 3.0753 3.3294 .láa& , 3. 8380 506 ~5"K"K 3929 3958 3983 3998 2fðì2 4020 4029 --- 4037 4-cf2ï2 4047 4052 4054 4059 4064 4485 . 504 3888** 3944 3978 3983cnM) CHART TIME FXPIREID... - - - - - - - - - 24 h Ticket ou r No. I Third , I Flow Period . I Time Defl. I PSIG .000" Temp. Corr. - F hour 12 599128 Third Closed In Pressure TimeDefl. La t+8 I' P:IG 000" 9 fJ Temp. . Corr. . , ! \ , , Minutes REMARKS: 39 * INTERVAL = 5 MINUTES ** INTERVAL = 23 MINUTES. *** ~ = ~t~. C =~HUKt-~HANbT. -ì I CTE = READ AT THE END OF 132.9 MINUTES WHEN CHART TIME EXPIRED... , PRINTED IN U.S.A. ZIT SPECIAL PRESSURE DATA LITTLE'S Drill Pipe or Tubing ................ Reversing Sub ...................... Water Cushion Valve ................ Drill Pipe ........................ Drill Collars ....,................. Handling Sub & Choke Assembly. . . . . . DuolCIPVolve ..............,.... DuolCIPSampler .....,......... Hydro-Spring Tester ..........".... MultipleCIPSampler ..........,.... AP CASE &'3~fì&g&&t ...........,........ APRunningCase .............,.... Hydraulic Jar """" """""" VRSafetyJoint ....., ... .. Pressure Equalizing Crossover. . . , . . '. . . PackerAssembly................... g~(1¡m&~~. P~RFORATlQN$. . . , . . . . Packer Assembly.:..'........,...... FlushJointAnchor """""""'" Pressure Equalizing Tube.. ..,...... Blanked-Off B.T. Running Case. . . . . . . ~ktäW&~~~. .~'.~ ~. ,~~~~. . . '" . Anchor Pipe Safety Joint. . . . . . . . . . . . TEMP. RECORDER I&:&&&~................... Distributor """""""""""" Packer Assembly......:............ Anchor Pipe Safety Joint. . . . , . . . . . . . SideWall Anchor """""'" "" Drill Collars .....,................ 8 FlushJointAnchor.................. ~I Blanked-Off B.T. Running Cose . . . . . . . . U TotaIDepth.......................' 0.0. 511 3~1I 3~1I ~ 3.8711 3.8711 3.8711 3.8711 5.7511 2.87" ~ ~ 3.87" I. D. 2.2511 2.76411 2.76" .62" 3" 3" 111 2.4" 2.4" "°11" II_""INT[O IN U.8.A. EQUIPMENT DATA '- LENGTH 1 ' 8200' 4.50' 6.021 5.871 DEPTH 8189' 8195' 4.57' 8200' 4.59' 8204' 5.07' 3.23' 3.95' 8.751 ~ ~ 1 .051 82171 --.B229 , 82331 82381 LITTL['. ~') ,. Each Horizontal Line Equal to 1000 p.s.i. "...-. "...."' _. ""..."".".", """.""-"- / NOMENCLATURE b = Approximate Radius of Investigation. . . . . . . . . . . . . . . . . . . . . . . . Feet bl == Approximate Radius of Investigation (Net Pay Zone hI) . . . . . . . . . Feet D.R.=DamageRatio ........................................,.- EI GD = B.T. Gauge Depth (From Surface Reference) . . . . . . . . . . . . . . . . . . . Feet h = Elevation ..............................................Feet = Interval Tested .........................................Feet hI K = Net Pay Thickness .......................................Feet = Permeability ...........................................md KI = Permeability (From Net Pay Zone h,) ........................md m = Slope Extrapolated Pressure Plot (Psi1/cycle Gas) . . . . . . . . . . . . . . psi/cycle OFI=Maximum Indicated Flow Rate ............................MCF/D OF2=Minimum Indicated Flow Rate ............................MCF/D OF3 = Theoretical Open Flow Potential with/Damage Removed Max. . . . . MCF/D OF4 = Theoretical Open Flow Potential with/Damage Removed Min. . . . . MCF/D Ps PF = Extrapolated Static Pressure ...............................Psig. = Final Flow Pressure ......................................Psig. P ot = Potentiometric Surface (Fresh Water *) ..............,....... Feet Q = Average Adiusted Production Rate During Test. . . . . . . . . . . . . . . . bbls/day Q I = Theoretical Production w/Damage Removed. . . . . . . . . . . . . . . . . . bbls/day Qg = Measured Gas Production Rate ............................MCF/D R = Corrected Recovery ......................................bbls rw = Radius of Well Bore ......................................Feet t = Flow Time .............................................Minutes t 0 = Total Flow Time .........................................Minutes T Z == Temperature Rankine ....................................oR = Compressibility Factor ....................................- }J = Viscosity Gas or liquid ...................................CP Log = Common Log * Potentiometric Surface Reference to Rotary Table When Elevation Not Given, Fresh Water Corrected to 100(1 F. (I /." Formation testing Servict; Report ~ Œ ~ Œ ~.W Œ ~ SEP 1 6 i~'l4 D1yrslON OF O!L AND [;115 ANtH O-RAGB HAlllBORTON SERVICES DUNCAN, OKLAHOMA FLUID DATA Ticket Number H?"i~)lJrton ANCHO AGE District R 599126 Formation Tested Elevation - 9?~~ KB Net Productive Interval 1 0028' - 1 0036 ' - 10080- 92 ' ppm All Depths Measured From Ke 11 y Bush i ng ppm Totol Depth lQ4~ ppm Main Hole/Casing Size 9 5/811 Pi. 711 ppm Drill Collar Length I.D. ppm Drill Pipe Length 10000' I.D.? . 76411 Packer Depth(s) 1 OO?O I cp Depth Tester Valve 1 OO~-- SAMPLE Date 8-1-74 Sampler Pressure Recovery: Cu. Ft. Gas cc. Oil ce. Water ce. Mud Tot. liquid cc. P.S.I.G. at Surface Kind of Job HOOK WALL ---'-- - MR. BOATMAN Tester Wi tness Gravity Gas/Oil Ratio ° API @ OF. cu. ft./bbl. CHLORIDE CONTENT g~~~i~~tor KENAI DR I LL I NG COMPANY EQUIPMENT & HOLE RESISTIVITY Recovery Water Recovery Mud Recovery Mud Filtrate @_OF. @ of. - @ - of. @_oF. @_oF. Mud Pit Sample Mud Pit Sample Filtrate Mud Weight TYPE AMQ..UNT 2200 pSI Gas vis - Surface Choke Depth Back Ft. Pres. Valve 9998' !-:,II Cushion Recovered 210 Feet of Mud Recovered Feet of Recovered Feet of Recovered Feet of Recovered Feet of MR. WESTER BC S DATA Ft.::: HOLESFt. ::E: Ft. - Ft. Ft. Bottom Choke 5/RII »!! ~ 2 ð: p "'T1 ^ Ò (T 3 Z -t :Þ !D t-f III .... f1) G1 .. :Þ ~ C/) ~ 'T1 t-f Iï1 ï 0 - Tool opened for a 44 minute first flow, closed in on surface with no pressure Remarks increase. Opened on ~II choke at surface after 11 minutes. Pressur~EL~down to 950# PS I in 44 rnJ nu.!?s !_-~19J>_~__toqLfor_5Lmi llute_fj_r.$~LQ.s~cLtn_pJ:e.s.s..u~----'~ Reopened tool for 120 minute second flow with no increase at surface. Opened on ~II g _.~hoke aJld b l~9-.tQ_ErChJlacL~ 1 i ght blow for r.emain.d.eLo.f-.te.5t. Cl os..e.cLto.o.L.£o.r ~ 125 minute second closed in pressure. ^ (T :z :Þ t-f TEMPERATURE Gauge No.J]82 Gauge No. 285 7 Gauge No. Deoth: 10008' Ft. Dcoth: 10012 ' Ft. Deoth: 24 Hour Clock 12 Hour Clock Blanked Off Wo Blanked Off No 3381 10032' Ft, 24 Hour Clock Blanked Off Yes Est. of. 10041' ~ Actual 137 OF. Pressures Pressures Pressures Field Office Field Office Initial Hydrostatic 4'513 4537 4539 4544 +-" FJ Initiai f--~6_- ~~..95 2677 .1694 ~'~ ow Fin~1- __J_l58 - __1..199.._- 1184 1200 Q. Closedin 2686 2~"r~_______~65L_- 2672 "0"0 Initiol 1206 1208 1184 1205 §'~ Flow" Final 12ï 97 124 - 99 ~Q. --- Clos~.d in 2352 2364 2384 ._23J~4 Initial '?"8 Flow 'J: '¡: Final f-æ -- - .- Closed in ---- _!inC},! Hydros~_".. 45T3= - 452f4= !ï~39 --- .lï549- ,.4.~!lQ .. Field 4540 2699 1204 2674 -121) 4 123- 2380 Office ~-S-ti~ -¿70a- --"1"208 "Lo8b I~~I NT ~3/3 - A...565_- rOHM 'uI""'PIIINTEO IN U,S.A. FORMATION TEST DATA TIME OJ Tool AM. ~ Opened 1 : 14 =~M=. g Opened AM. ~ Bypass 9: 00 ::P:.M:: Reported Computed Minutes Minutes - VI -q:"4 ~ g- :Þ ï T20- ~ ---rzs- ~ 43 btl - 120 1 Z5 - - - -- .. LIT1'LE'S 8H74 ~M 8/73 VIr- ~~ noD '0 , - ~r- ~O un . 0 ,;:!'. ;00 :J:J eD 7' CJ c: ........ I r- III 0 '" 111 Z 0 3 111 -Þ Z , ~N f1) z ? -t f1) ~-Þ Z ? --J 0, a N a ~ , III [~ -0 ~-Þ 111 0) < --J 0 - - -0 OJ CJ c: :z t-f 0 :z 0 t-i r I--- (") r-O ~ 3: III -0 f1) :þ 02 ~ -< ~ '0 Q" 3 un g :þ '< r z- 0 'T1 ~ 0 ;0 :z: t-i Þ ~ FLUID Sampler Pressure Recovery: Cu. Ft. Gas cc. Oil cc. Water cc. Mud Tot. Liquid cc. Gravity Gas/Oil Ratio Recovery Water Recovery Mud Recovery Mud Filtrate Mud Pit Sample Mud Pit Sample Filtrate Mud Weight TYPE Cushion Recovered Recovered Recovered Recovered Recovered Remarks TEMPERATURE Est, Actual - Initial Hydrostatic Initial 'E~ Flow ü: t Final Q. Closed in Initial Final "- Closed in Initial "E'8 Flow :ë'C Final I-~ Closed in Fin~1 Hydrostatic "'0"'0 a.S! Flow u"" QIQI v>Q. FORM t8t-.-PRINTED IN U,S,A. AMOUNT SAMPLE DATA P.S.I.G. at Surface ° API @ OF. cu. ft./bbl. CHLORIDE CONTENT RESISTIVITY -@ of. -@ OF. - @ - of. - @ - of. - @ - of. vis Ft. Depth Back Pres. Valve Feet of Feet of Feet of Feet of Feet of FOURTH GAUGE: Gauge No. 28b6 Gauge No. DeDth: 10036 1Ft, Deoth: J 2 Hour Clock Blanked õffTes OF. OF. Field 4559 2700 1192 2676 1192 122 2.3.8 3 Blanked Off Pressures Office Field 4562 2708 12.06 2686 1-2.13- 97 2.372 ~559__- ._.45B2- --.. Date Kind of Job 8-1-74 HOOK WALL - Tester MR. BOATMAN Ticket Number 599126 ~~Itl:~~rton ANCHORAGE Witness Drill ing ControctorKENA I DR I LL I NG COMPANY EQUIPMENT & HOLE Formation Tested Elevation Net Productive Interval ppm All Depths Measured From ppm Total Depth ppm Main' Hole/Casing Size ppm Drill Collar Length ppm Drill Pipe Length Packer DepthCs) cp Depth Tester Valve Surface Choke Gauge No. Ft. Dcoth: Hour Clock Blanked Off Pressures Office Field - FORMATION TEST DATA Ft. Hour Clock Pressures Office MR. WESTER BC S DATA LD. LD. Bottom Choke Tool Opened Opened Bypass Reported Minutes - - - - LITTLI!:'S DU,", 8M 8/" TIME OJ A.M. §5 P.M. g A.M. ~ P.M. Computed Minutes - - - - Ft. ~ Ft. ::E: Ft. Ft. Ft. >~ 3: '"'/':I C1I 3 ä: 0 ~ 7' 0 rr1 3 Z ;;i )::>0 VI I-t ... C1I ., Ci) < )::>0 e.. (/) < C1I (I'Ir Q~ nca " ~ -ir ~o un . 0 I:!'. ;;0° ::J::J to ^ '-I I rO ~ ~ c: CII Z 0 3 CII .þ Z I ~ ~N Z ? -f CII - VI -+ z..þ ? ." I-t rr1 ï 0 --' C> C> N -iC> CII '" [ I ~-' CII C> ;! ..þ Q..cn --' - () 0 C ::J .... '< -0 OJ 0 7' rr1 Z )::>0 I-t c:: :z 1-1 0 :z 0 1-1 ï - r () (1) 0 0 -. VI -:S. (1) -0 0):::> ~ ::2: ~ -< , ~O 3 ." u 0 () ~ ):::> Z ï 01-1 3 Ï (1) 0 ;0 :z 1-1 :Þ lI'I .... 0 .... (1) )::>0 ï ):::t (/) 7' ):::t ...7 Gouge No. 3382 Depth 100081 Clock No. 8739 24 hour T~~~t 599126 First First Second Second I Third Third Flow Period Closed In Pressure Flow Period I Closed In Pressure I Flow Period Closed In Pressure I Time DefLI PSIG I' Time DefL II L t + () PSIG I Time Defl. PSIG Time Defl. I L t + () PSIG I Time Deft PSIG Time Defl. l t + () " PSIG 000" Temp. 000" 09 () Temp. I 000" Temp. 000" 09 Temp. 000" Temp. 000" 09 Temp. . Corr. I ' Corr. I' Corr.' () Corr. I' Corr.' () Corr, 0 .0000 12695 '.0000 1199 (.0000 11208 .0000 97 1 .0273 ;2695* .0231 1842** .0090 1208 OC .0497 1342**-J\ 2 (.11-«11112695 OC .0396 2019 .0682 447 .0828 1672 3 .0478i2286 .0561 2160 1.1363 1121 .1159 1866 4, .0683 11943 .0726 2260 .2045 97 .1490 1993 5 ,0888 í1691 ,,0891 2352 1,2726 97 .1821 2079 6 .1093 1462 L~J056 2429 .3408 97 .2152 2148 7 .1298 ¡1254 .1221 2495 .4090 97 .2483 2202 8 . 1500 1199 i. 1 386 2548 I .2814 2245 9 ! . 1551 2598 .3145 2283 10 ¡ .1716 2643 .3476 2314 11 ¡I. 1880 2676 .3807 2338 12 .4140 2364 13 I 14 i 15 I I Gauge No. 2857 Depth 100121 Clock No. 4485 12 hour 01 .0000 12694 .0000 ' 1200 .11111111 1205 .11111111 99 I 1 .053112694* .0465 1814** l.II/tlll r208 UC) .0994 1301**~ 2 (.0620 12694 OC .0797 2002. 1338 LfZr8' .1656 1650 3 .0929 2337 .1129 2139 .~b/b T2T .2318 1853 4 . 1 327 11 998 . 1 461 2257. 4014 TO1 . 2980 1 988 5 .1725 1724 .1793 2347 .5352 99 .3642 2078 6 .2123 1496 .2125 2423 .6690 99 .4304 2147 7 .2521 1281 .2457 2491 .8030 99 .4966 2200 8 .2920 1200 . í.1 IHY ::>545 .5628 2245 I 9 ~l?l ?~q4 .6290 2279 1 0 ~4~~ ?n~R .6952 2313 11 i7qn ?F\7? .7614 2340 12 .8280 2364 13 14 15 ! Reading Interval 6 5 ?O 1 () I Minutes REMARKS: *Interva1 = 8 minutes **Interva1 = 7 minutes ***Interval = 15 minutes OC = Ooened choke J,\ . FORIo4 1B3-PRINTED IN U,S.A. SPECIAL PRESSURE DATA LITTLE'S 93916 SM Bin Gouge No. 3381 . First II First . Flow Period I CI?sed In Pressure ¡Time Defl.! -rSIG I Time Defl. I Log t + B .000" é::;~' Ii .000" B 0 I .0000 I 2708 I!. 0000 I 1 .0271 I 2708* I .0233 2! ( .0310 ! 2708 O( ) .0400 ! 3 .0474 12331 .0567 4 .0677 12010 .0734 51 .0880 11733 I .0901 6. .1083 11505 I. 1068 7 . 1286 i 1287 I. 1235 81 . 1490 i 1208 I. 1402 I 9 I ! .1569 10 I ~ 11 I [ . 1900 12 I I . I i f 13 14 151 Gouge No. 2856 Q] . ~~~~ I ~~~~ 1 I . I 2i ( .0650 i 2708 oqry 3 .0961 2350 4 . 1373 I 2017 5 . 1785 1741 6 .2197 1513 7 .2609 1 300 8 .3020 1206 9 I I 101 1 1 ì 121 --r 13 14 IS .0000 .0480 .08231 . 1166 . 1 509 . 1 852 .2195 .2538 .2881 .3224 .3567 .3910 5 mlDutes i \J.. \ FO"'" '83-PRINTED IN U.S.A. Depth 10032' " Clock No. 8420 I Second . Closed In Pressure ~et 24 hour No. I Second " Flow Period PSIG II Time Defl. PSfG Temp. I 000" Temp. 1 ;~~ II. ~OOO 12~~rr. 1833** IC.Ol00 1221 OC 2017 .0672 467 2157 I' 1343 123 2267 .2015 103 ~368 .2686 101 2436 .3358 101 2505 ~030 ~Ol 2561 2605 2650 26R6 Third . Flow Period PSIG I Time Deft I PSIG Temp. 000" Temp. Corr. . Corr. 101 r 1265** 1652 1865 1990 2083 2l5.Q 2203 ..224.a 2287 ?319 ?14fi ?171 Depth 1206 1821 ** 2ðì2 2156 2265 2358 2433 ]2499 2555 2606 2647 2686 Time DefI. Log t + B .000" B .0000 .0498 .0830 . 1162 . 1494 . 1826 .2158 .2490 2822 .3l5A. II . ;Ä~~ : LmíLI I I I~ 10036' .0000 I( .0200 . 1378 .2756 .4134 .5512 .6890 .8270 1213 1218 OC 479 124 102 100 100 97 Clock No. 6729 .0000 .1027 . 1 71 3 .2397 .3082 .3767 .4452 .5137 .5822 .6507 .7192 .7877 .8560 97 1278*** 1646 1855 1988 2078 2151 2204 2251 2287 2319 23.4B. 2372 20 **1 nterva 1 =T minutes - 10 U 'f(7('f( 1 nterva J?l5 mi nutes SPECIAL PRESSURE DATA 12 hour 599126 Third Closed In Pressure Time Defl. ILo t + B .000" g e PSIG Temp. Corr. ,vdnutes I-ITTl.E"S 93976 5,.. 8/73 Drill Pipe or Tubing ............,... Reversing Sub ...................... WaterCushionYalve ................ Drill Pipe ........................ Drill Collars ...................... Handling Sub & Choke Assembly. . . . . . DualCIPValve """"""""'" DualCIPSampler """"""""" Hydro-Spring Tester .............,.. MultipleCIPSampler ........,...... Extension Joint """""""""" APRunningCase .....,...{~)..... Hydraulic Jar """" ".,..,.".. VR Safety Joint. . . .. . .,. Pressure Equalizing Crossover. . . . . . . . . PackerAssembly................... Perforations Distributor........................ Packer Assembly................... FlushJointAnchor """""""'" Pressure Equaliz'ing Tube.. ...,. .. Blanked-Off B.T. Running Case. . (.2), . DriliColiars """"""""""" Anchor Pipe Safet't. Joint. . . . . . . . . . . . lemp. Recorder Packer Assembly................... Distributor .............,.......... Packer Assembly................... Anchor Pipe Safety Joint. . . . . . . . . . . . Side Wall Anchor """"""""" Drill Collars """""'........,.. B FlushJointAnchor.................. ~ Blanked-Off B. T. Running Case. . . . . . . . U Total Depth ,...................... "0"'" 117-r'nINTIlD IN V.e.A. ':J<ET NO. 599126 O.D. J. D. LENGTH DEPTH 5" 2.25" l' 3k" 2.764" 10000' :;> 3k" 2.76" 4.41' 2 3.8]11 __~B 7 II 5. 17 1 9998' _-.l.ß 7 II .62" 5.77' 100031 3.87" 3" 3.87" 1" 5.75" 2.4" 2.87" 2.411 3.87" 3.8711 EQUIPMENT DATA -q..591 4.67' 3.251 3.95' 8.76' 4.03' 4.08' 1.04' 100081 10012' 1 0020 ' 10032' 10036 ' 10041' 104611 PBD LITTLII'S .:). '. ...' Each Horizontal Line Equa " .. .'--., / r--- '\....) I-) ,-",Y NOMENCLA TURE b = Approximate Radius of Investigation. . . . . . . . . . . . . . . . . . . . . . . . Feet bl = Approximate Radius of Investigation (Net Pay Zone hI) . . . . . . . . . Feet D.R.= Damage Ratio .............,............................- EI GD = B.T. Gauge Depth (From Surface Reference) . . . . . . . . . . . . . . . . . . . Feet h = Elevation ..............................................Feet = Interval Tested .........................................Feet hI K = Net Pay Thickness .......................................Feet = Permeability ...........................................md K1 = Permeability (From Net Pay Zone hI) ....................... .md = Slope Extrapolated Pressure Plot (PsF/cycie Gas) . . . . . . . . . . . . . . psi/cycle m OFI=Maximum Indicated Flow Rate ............................MCF/D OF2=Minimum Indicated Flow Rate ............................MCF/D OF3 = Theoretical Open Flow Potential with/Damage Removed Max. . . . . MCF/D OF4 = Theoretical Open Flow Potential with/Damage Removed Min. . . . . MCF/D Ps PF = Extrapolated Static Pressure .,.............................Psig. = Final Flow Pressure ......................................Psig. P ot = Potentiometric Surface (Fresh Water *) .....,................ Feet Q = Average Adiusted Production Rate During Test. . . . . . . . . . . . . . . . bbls/day Q I = Theoretical Production w/Damage Removed. . . . . . . . . . . . . . . . . . bbls/day Qg = Measured Gas Production Rate ............................MCF/D R = Corrected Recovery ......................................bbls rw = Radius of Well Bore ......................................Feet t = Flow Time .............................................Minutes to = Total Flow Time ...............'..........................Minutes T Z = Temperature Rankine .....................................oR = Compressibility Factor ....................................- jJ = Viscosity Gas or Liquid ...................................CP Log = Co'mmon log * Potentiometric Surface Reference to Rotary Table When Elevation Not Given, Fresh Water Corrected to 100° F. Formation resting Servic'~ Report íõ) Œ @ Œ ß ~. ~ IDj, ~ .; p 619f4 t.\Wr:hcd~ IT\" OlL.AND f;à5 J:.,~. """),:\\.'f' ,¡\~H_~~ \ tí,\J\h,l, ~ æ ~ Œ ~.~ æ ~ SEP 1 6'974 IHVlSHUi OF ŒL AND GAS ANtHnRAG~~ ~ æcc;æ~WŒ~ . SEP D""l!f'fON -" " , ."1' f ¡'"~ ''\ ,(I '" !~!.;1 . ,.~t Lt, rU1.U t~A-5 !\.1"("~"ÌlI~\('TI W.~ "r:~1'!~/,\~,.~I. HALLIBORTON SERVICES DUNCAN, OKLAHOMA FLUID Sampler Pressure Recovery: Cu. Ft. Gas cc. Oil cc. Water cc. Mud Tot. Liquid cc. Gravity Gas/Oil Ratio Recovery Water Recovery Mud Recovery Mud Filtrate Mud Pit Sample Mud Pit Sample Filtrate Mud Weight cu. ft./bbl. Formation Tested - CHLORIDE Elevation 92.61 Ke l1.v bush i nQ CONTENT Net Productive Interval 9884- 99101 ppm All Depths Measured Fro~e 11 y bush i ng ppm Total Depth EB.D 99501 ppm Main Hole/Casing Size_9 5/8 & 711 ppm Drill Collar Length - LD. ppm Drill Pipe Length__~I.D._2. 764~1 Packer Depth(s) 9-.8791 cp Depth Tester Valve 98621 SAMPLE DATA Ticket Number Dote 7-29-74 P.S.LG. at Surface Kind of Job WATER SHUT OFF Halliburton District - Tester C. H. BOATMAN Wi tness ° API @ Drilling Contractor KENA I DR ILL I NG COMPANY OF. E QUI P MEN T & H 0 L E RESISTIVITY -- @ of. @ of. - @ - of. @ of. @ of. vis 598849 ANCHORAGE D. WESTER SM DATA S TYPE AMOUNT Depth Back Cushion wa ter 4200 Ft. Pres. Valve Flowed Recovered 4 bb 1 s . ,*Xt of water cush ion 98571 Surface Bottom Choke Bubble hose Choke 5/811 - Recovered 9692 Recovered 5 Recovered Recovered Feetof qassv water Feet of sand Feet of Feet of Remarks Set packer at 99151 for dry test with Hol.e.La..L9..9J9-99201. with light bubble bl.IDLto rfP~rf in / m;nrltpc; nPil d remai.ncier-Of. tes t. Op.e.n.e.d tes tpr P ulle.cUoo.5.e- Ft. ::E: Ft. Ft. Ft. Ft. >:1 f 8ð: ? ." ... 0 3 ;;f Ã ~ z ~ ::Þ < I-f 0 <" G) (1 ::Þ V> " I-f m r 0 VIr- /1)/1) (\ u.) . a' - -Ir- ~o -0(\ . a ,::!', ;00 ;):J 'P ........ .þ. r- /1) 0 ~ ^ Z ~ 0 /1) z c: ...... ...... ~N Z ~ -I II) -'" ... Zw ~ 1..0 CO ........ 1..0 ~ ~ -IUl m a ... tÞ - a. :J ... tÞ ;! 0 ~nd reset R9..ÇJœr~~.a.m:LQ-p-ene.cLte.s.ter witb.-S..tron9-hlow decreasinfh-Water & I- n 0 c: Qas to the_. Ul'.nce in 83-'Ili~ing Wow. Closed tooLfor 120 minlfte clo-S.ed-~ in oeriod Gauge No. 3382 Gouge No. 2857 Gauge No. 3381 TEMPERATURE Depth: 9867 Ft. Death: qR71 Ft. Death: 4X4:1 Ft. 24 Hour Clock 12 Hour Clock ?ll Hour Clock Est. of. Blanked Off no Blanked Off no Blanked Off\l~, Initial Hydrostatic Initial 'ti '8 Flow i.i:'~ Final Q., Closed in "'0 Initial \. 0 Flow 8ï::: Final J\~ Closed in Initiol "2"2 Flow J:'L: Final ....~ Closed in -Yin~.~.J~Xdros!~ _..4.4.L8_._. _44A2.::4-42.3 - .4A3.6.=-CIE_. .__44].8- -4.451--=-4..4.3.5. CTE = Chart time expired. 9900. Actual 132 OF. 4.4..1 R 1828 18.28 2067 2114 3518 3731 rO"M 181-PJlINTF.D IN U.8.A. , , v Pressures Pressures Pressures Field Field Office Office Field Office M4? - llll ? 1 MJL .A.4.3.6.~lL4.l9. --44 -1-8- -445L..... A 1117 1861 184-6 1851 1A65 1R70 ~ -_18_6-1-- -_-.1.8 46 lß5L r---lB.6.L- . 1 R 70 2_Q8ß 20~J /llïh /1]1L- -2,OQh -2.14.3. 21LL 2112 2l.59- ?l ~q .-3..56.3 - --3AfiQ 1~~R 1J;f\A 31ll - .~ -3JM- __.3ILll --- - FORMATION TEST DATA TIME Tool AM. CO Opened q. J;n )(9.~. ~ Opened M.M<) 0 1.1. C Bypass ~ . nh P.M. G) :J: Reported Computed Minutes Minutes - VI - -+ 6-3-~ 52 65 50 - - 139 120 - - - - LITTl.l!'S IIU74 ~M 0/73 139 120 ^ m z ::Þ I-f - c: :z: I-f a z a I-f ¡;r a X; n 09 :E ~ ::I ï:J ~ » ri:z 3 -< go ~ .,., Z n 3 » tÞ r ........ ï1 0 ;0 z ........ ::Þ :Þ r :Þ V> 7' ::Þ Drill ing Contractor KENAI DRILLING COMPANY EQUIPMENT & HOLE Formation Tested Elevation Net Productive Interval ppm All Depths Measured From ppm Total Depth ppm Main Hole/Casing Size ppm Drill Collar Length ppm Drill Pipe Length Packer DepthCs) cp Depth Tester Valve FLUID DATA Dote 7-29-74 SAMPLE Sampler Pressure Recovery: Cu. Ft. Gas cc. Oil cc. Water cc. Mud Tot. Liquid cc. P.S.I.G. at Surface WATER SHUT OFF Kind of Job - Tester C. H. BOATMAN Gravity Gas/Oil Ratio ° API @ OF. cu. ft./bbl. CHLORIDE CONTENT RESISTIVITY Recovery Water Recovery Mud Recovery Mud Filtrate -@ @ -@ -@ @ OF. of. OF. of. OF. Mud Pit Sample Mud Pit Sample Filtrate Mud Weight TYPE vis Depth Bock Pres. Valve Surface Choke AMOUNT Cushion Ft. Recovered Feet of Recovered Feet of Recovered Feet of Recovered Feet of Recovered Feet of Remarks Fourth gauge TEMPERATURE Gouge No. 2856 Gouge No. Deoth: qRql1 Ft. Deoth: --12- Hour Clock Blanked Offvp, Gauge No. Ft. Deoth: Hour Clock Est. Blanked Off Blanked Off OF. Actual Pressures Pressures Pressures OF. Field Office Field 0 ffice Field Initial Hydrostatic Initial t; '8 Flow ¡¡'~ Finol 0. Closed in Initial Finol Closed in Initial "E"8 Flow :.ë ï: Final I-æ Closed in Final Hydrostatic 44h 1 -.4.467- 44(:) 18.~- _1&F.7 1 H4L 1 Ah7 7090 ?Q9(:) ?1111 -216.1 1551 -C..T E i:J-o ~,g Flow u'" CIJCIJ ",0. - - - 4A60~~~ r.TF - rhrlrt tim~ t:wnirprf 10RM IÐI-PRINTED IN U.I.A. FORMATION TEST DATA Ticket Number Halliburton District Witness Ft. Hour Clock Office 598849 ANCHORAGE D. WESTER SM DATA I.D. I.D. Bottom Choke Tool Opened Opened Bypass Reported Minutes - - - - LITTLE" 83974 8M ./71 S TIME A.M. P.M. A.M. P.M. Computed Minutes - - - - V1r 1',)/1) nil) . 0 ' 1- 4õ ~o 'On .0 ,= ~o :1:1 cO r I',) 0 ~r;: z 30 tÞ C "-I .þ. Ft. Ft. z --I --I Ft. ~ ::EN tÞ Ft. Ft. z ? -i II) -'" ""w >!! Z ~ 85: ? CI 'TI .., 0 3 -. (II III .... II> ... ^ m z )::t I-f < CI <" 111 G> )::t (/) " I-f m ï 0 ~ -i00 œ"-l ;:~ Cl. 5'1 m~ ~~ -Ul a - () 0 C :I -+ -< r;: m :z ):0 .-. OJ 0 :::0 0 c:: G') :r: c: :z .-. a z r g:a "'~ t1). 0 ~ :I(J ~o ri~ 0"U 3):0 ~z ~-< Za 3" t1) (J :Þ . ~ ï1 a ;0 :z ~ ::Þ - V1 .... 0 .... !II þ . )::t (/) ~ .", Gauge No. 3382 Depth 98671 Clock No. 8739 24 hour Ticket 598849 No. UI<YF' I t.~ I DRYF' Itt.;) 1 Second Second I Third Third Irst Irs Flow Period Closed In Pressure Flow Period Closed In Pressure Flow Period Closed In Pressure Time Def!. PSIG Time Def!. Log t ~ (} I PSIG Time Defl. PSIG I Time Def!. Log t + (} PSIG Time Defl. PSIG Time Def!. Log t + (} PSIG .000" Temp. .000" Temp. .000" Temp. .000" Temp. .000" Temp. .000" Temp. CorI'o CorI'o CorI'o (} CorI'o Corr. B CorI'o 0 .0000 1861 nnnn 1861 .0000 2143 .0000 3563 . ., 1 .¿It)U I 1861 . 1 I¿U ¿UtRS .0637* 2595 .U267 3703 2 . 1307 2981 .0534 3727 3 . 1978 3264 .0801 3741 4 .2648 345:';' .1068 3748 5 .3319 3333 . 1335 3755 6 .3989 3451 . 1602 3758 7 .4660 3563 . 1869 3762 8 I .2136 3765 9 I .2403 3767 . 10 .2670 3770 11 .2937 3772 12 .3204 3772 13 .3471 3774 14 I .3738 3777 15 I I . 4000 :i III Gauge No. 2857 Depth 9871' Clock No. fi7?q ? hour 0 I. 0000 1851 .0000 1851 .0000 2132 1 !.4450 I 1851 I .3490 2076 . 1 31 2* 2572 2 .2693 2961 NO NF Ht-ntH III-n 3 .4074 :i? 41 .4 I C::11C::11 :i4:il rH ART TTM¡: . 5 h~~~ ~~l? .FXPTRFn 6 R?lf\ ~4_i7 7 (R~l() ~4f\q*-; i) 8 - - # 4h1H) - 9 10 1 1 12 13 14 15 I Reading Interval i LU ! ~ I I I Minutes REMARKS: *First interv;¡l is """"'1 to 1)9 m;nllt¡::¡c::: **Ro~rf rit thp pnri ('If ;¡ IIII' x;m~t¡::¡lv l?:i m;nIJt¡::¡c::: L ("h~Y'+ +;mo ovn;Y'¡::¡rf r ., T " .A, ~O;¡... !SJ-PRINTEC IN U.S.A. SPECIAL PRESSURE DATA LITTLE.S ~U76 ~M S/73 3381 9892' Clock No. 8420 24 hour Ticket .598849 Gauge No. Depth No. Utþ1 tl t::i I URYF. Il:::i j I I ,rs Irs Second Second Third Third Flow Period Closed In Pressure Flow Period Closed In Pressure Flow Period Closed In Pressure I Time Def!. PSIG Time Def!. Log t + 0 PSIG I Time Def!. PSIG Time Def!. Log t + 0 PSIG Time Def/. PSIG Time Def!. Log t + 0 PSIG Temp. Temp. Temp. Temp. Temp. Temp. .000" Carr. .000" () Carr. .000" Carr. .000" () Carr. .000" Carr. .000" 8 Carr. ./1111111 1870 .0000 1870 .0000 2159 .0000 0 .:St)b~ 1 . ~ I I U 1870 . 1 740 2096 .0636* 2593 .0267 3705 . 1305 2985 .0534 2 ~i /"1/ 3 .1974 3265 .0801 :i740 4 .2643 :i4~7 10fiR :i747 5 .3312 3334 1:i:iF; ~7~? 6 .3981 ~4~~ 1602 :i7~7 7 4fi~O :i~fiR 1Rfiq :i7 F)q 8 i ?l:ifi ~7h? 9 ?40~ ~7h4 10 ?h70 . ?,7h7 1 1 ?Q~7 ?,7hQ 12 ~?()4 ~7hQ 13 ~Ll.71 ~771 14 ---- ~771 ' .~ r.u~ 15 I ! Ilnf)f) ':1.77/1 Gauge No. 2856 Depth 9896' Clock No. 4485 12 hour 01 .0000 1867 I .0000 1867 .0000 21fi1 1 I .4200 . 1867 .3490 2095 1/71 * 2586 2 ?fiOR ?qR~ 3 I . ~q4~ ~?h? 4 F;?R~ ~4h(). 5 hh?n ?'~LI." a' -I", 6 7Q~R ~LI.~7 7 ' """"- *-1< ~""~, rhiH' . 4( Ilf I~ 8 Q?Q~ f øvr I; V'øn - 9 T 10 1 1 121 13 14 I 15 I Reading Interval 20 8 Minutes REMARKS: *Flrst interval is equal to 19 minutes. **Read at the end of approximate1v 136 minutes when chart time explred. PI FO~"" '53-PRINTED IN U,S.A. SPECIAL PRESSURE DATA LITTLE'S 5135176 5101 8/73 Drill Pipe or Tubing .........,...... Reversing Sub ...................... Water Cushion Valve .............,.. Drill Pipe ..............,......... Drill Collars ...................... Handling Sub & Choke Assembly. . . . . . DualCIPValve """"""""'" Dual CIP Sampler """"""'" Hydro-Spring Tester ......""""" MultipleCIPSampler ............... Extension Joint ..................,. APRunningCase .............,.... II II Hydraulic Jar ........ """""" VRSafetyJoint ..,.... .,. ""'" Pressure Equalizing Crossover. . . . . . . . . PackerAssembly................... --D1stTlMcn-...P.erfs............;... PackerAssembly................... FlushJointAnchor """""""'" Pressure Equalizing Tube.. """'" Blanked-Off B.T. Running Case. . . . . . . II II DrillCollars """"""""""" Anchor Pipe Safety Joint. . . . . . . . . . . . Temp. recorder Packer Assembly................... Distributor........................ Packer Assembly................... Anchor Pipe Safety Joint. . . . . . . . . . . . Side Wall Anchor """"""""" Drill Collars """"""""""" a FlushJointAnchor.................. ~l . Blanked-Off B.T. Running Case. . . . . . . . U Total Depth ....,.................. ,.nln4 IU-I'RINTItD IN U...A. _KET NO. O.D. I.D. lENGTH 511 2.2511 11 3.511 2.76411 98611 3. 511 2.7611 4.411 3.8711 .8711 5.171 3.8711 .6211 5.771 3.8711 3.8711 --3 II 311 J....59 1 4.671 ~ ---1 II -3.251 5.7511 2.411 3.951 2.R711 ? 411 R.7ñl 3 8711 3.8711 4.031 4.081 3.8711 1.041 EQUIPMENT DATA 598849 DEPTH 98571 98621 ~71 98711 9R791 98921 98961 99001 LITTLI'. ." Each Horizontal Line Equal to 1000 p.s.i. r""" ~~) (J NOMENCLA TURE b = Approximate Radius of Investigation. . . . . . . . . . . . . . . . . . . . . . . . Feet bl == Approximate Radius of Investigation (Net Pay Zone hI) . . . . . . . . . Feet D.R.==DamageRatio ..........................................- EI GO == B.T. Gauge Depth (From Surface Reference) . . . . . . . . . . . . . . . . . . . Feet h ==Elevation ..............................................Feet ==Interval Tested .........................................Feet hI - Net Pay Thickness .......................................Feet K -Permeability ...........................................md K1 == Permeability (From Net Pay Zone hi) """"""""""'" .md m == Slope Extrapolated Pressure Plot (Psi2/cycle Gas) . . . . . . . . . . . . . . psi/cycle OFI==Maximum Indicated Flow Rate ............................MCF/D OF2==Minimum Indicated Flow Rate ............................MCF/D OF] == Theoretical Open Flow Potential with/Damage Removed Max. . . . . MCF/D OF4 == Theoretical Open Flow Potential with/Damage Removed Min. . . . . MCF/D Ps PF ==ExtrapolatedStaticPressure ...............................Psig. == Final Flow Pressure ......................................Psig. P 01 == Potentiometric Surface (Fresh Water") """"""""""" Feet Q == Average Adiusted Production Rate During Test. . . . . . . . . . . . . . . . bbls/day 0 I == Theoretical Production w/Damage Removed. . . . . . . . . . . . . . . . . . bbls/day 09 ==Measured Gas Production Rate ............................MCF/D R ==Corrected Recovery ......................................bbls fw = Radius of Well Bore ......................................Feet t = Flow Time .............................................Minutes t 0 = Total Flow Time .........................................Minutes T Z == Temperature Rankine ....................................oR ==CompressibilityFactor ....................................- }J = Viscosity Gas or liquid ...................................CP Log = Common Log * Potentiometric Surface Reference to Rotary Table When Elevation Not Given, Fresh Water Corrected to 100':' F. Formation Yesting Servic1é Report ~ œ ~ œ tW [Ë ~ SEP 1 6 'i~74 ÐlViSIUN OF O!L ANn CAS AN CH ORAGl': HALllHURTON SERVICES DUNCAN, OKLAHOMA FLUID Sampler Pressure Recovery: Cu. Ft. Gas cc. Oil cc. Water cc. Mud Tot. Liquid cc. Gravity Gas/Oil Ratio SAMPLE RESISTIVITY DATA 8-2-74 Dote P.S.I.G. at Surface Kind of Job ° API @ Recovery Water - @ - of. Recovery Mud - @ OF. Recovery Mud Filtrate - @ - of. Mud Pit Sample - @ - of. Mud Pit Sample Filtrate - @ of. Mud Weight TYPE Gas Cushion Recovered Recovered Recovered Recovered Recovered AMOUNT 21751/: psi 420 Feet of OF. cu. ft./bbl. CHLORIDE CONTENT vis HOOK WALL TEST Tester MR. BOA TMAN Ticket Number Halliburton District Witness Drill ing Contractor KENAI DRILLING COMPANY EQUIPMENT & HOLE 10000' 10020' 10003' 599127 AN æ ORAG E MR. WESTER PW S DATA Ft. & 10080 I - 92 h. ~ LD. I.D. 2.764" Ft. Depth Bock Pres. Valve 9998 Surface Bottom Choke 1/4" - 1/2" Choke 5/8" Formation Tested Elevation 92.6' K. B. Net Productive Interval Ho 1es 10028' -36' ppm All Depths Measured From Ke 11y Bush ing ppm Total Depth 10461 ' ppm Main Hole/Casing Size 9 5 / 8" - 7" ppm Drill Collar Length ppm Drill Pipe Length Packer Depth(s) cp Depth Tester Valve .. Field 1~563 2653 321 2237 149 222 Feet of Feet of Feet of Feet of Mud - gassy .. Remarks Opened tool for a 35 minute first flow oeriod with no increase in surface pressure. bled gas off to 2001/: psi before closing in. Closed tool for a 60 minute initial closed in pressure. Reopened tool for a 180 minute second flow period with no increase in pressure. Bled gas off to zero,-1!ght blow . remainder of test. Closed tool for a 239 minute final closed in pressure. Gauge No. 3382 Gauge No. 2857 Gouge No. 3381 Depth: 10008 Ft. DcDth: 10012 Ft. DeDth: 10032 Ft. 24 Hour Clock l2Hour Clock 24 Hour Clock - Blanked Off No Blanked Off No Blanked Off No TEMPERATURE Est. of. 100411 Actual 134 OF. Initial Hydrostatic Initial ~] Flow ü::¡¡ Final Co Closed in "0"0 Initial §,2 Flow u'- Final j(~ Closed in Initial "E"8 Flow :ë.: Final I-~ Closed in Final Hydrostatic '-ORM ,e'-PAINTED IN U.8.^'. Pressures Field 4537 2662 290 2233 .. 145 217 2138 Office 4570 2686 389 2250 150 220 2J6~ .. --- --- ~5J]___- ___4_~_7 7 CTE = Cha~t Ti.me Expired Pressures Office Field 4566 45/,.0 --- 2672 2674 371 344 2240 2282 144 149 208 -- 22~ 195.LC ~R 2159 -- --, CTE 4540 Pressures Office 4577 2686 364 1998 150 219 2167 4582 FORMATION TEST DATA - ------ -.,-, TIME Tool Opened Opened Bypass Reported AM. txJ 10: 57 Jè.M=. ~ A:M:: 0 c:: 7: 30 P.M. ~ Computed Minutes Minutes - 33 62 - 178 240 - - , - LITTLIt'S 831174 aM eh. Ft. Ft. Ft. - 35 60 - 180 239 - - v>r 1\)11) noD . 0 , - .....r ~o 'On . 0 .:!: ,,0 :J:J ? -....J r I\) 0 '" ID z~ 0 ~t:J c:: +:-- Z I :¿ ~N Z ? ..... ID - ~Ln >:!! Z ~ 25: ? ~ ." ~ (3 t%j 3 Z -. > Ib H '" -+ ~ (j) < > 0 Cf) <' Ib I-xj H t%j t-' t:J t-' 0 0 N .....0 ID .. '" -to ~ I :J it"" < C> 0 +:-- -0'\ t-' - - 9 c :J -to '< ~ H ~ H @ H 0 Z 0 H ~ - r(") (1) 0 ~ ~ (1) "d 0> ~ ~ ~ (;0 3 I-xj '0 g (") '< > Z ~ 0 H ~ t-xj 0 :;u ~ H > V> .... D .... I\) > ~ Cf) ~ r- ì v>r FLUID SAMPLE DATA Ticket 111/1) n.o Dote 8-2-74 599127 ' Q Number 1- ~r Sampler Pressure P.S. LG. at Surface ~o Kind Halliburton un . Q Recovery: Cu. Ft. Gas of Job HOOK WALL TEST District ANŒORAGE ' ::!. ;00 - :]::1 cc. Oil 'P cc. Water Tester MR. BOATMAN Witness MR. WESTER cc. Mud Drill ing Tot. liquid cc. Contractor RENA I DRILLING COMPANY PW S ....... Gravity ° API @ of. EQUIPMENT & H 0 L E DATA I Gas/Oil Ratio cu. ft./bbl. Formation Tested .p.. 92.6' K.B. z RESISTIVITY CHLORIDE Elevation Ft. CONTENT Net Productive Intervaltlo 1es 10026' - 36,' 10080 1- 92' Ft. I - Recovery Water @ of. ppm All Depths Measured FranKe lly Bushinu I-' I-' Recovery Mud @ of. ppm Total Depth 10461' ~ Ft. Recovery Mud Fi I trate -@ of. ppm Main Hole/Casing Size 9 '5/8" - 711 Mud Pit Sample @ of. ppm Drill Collar Length 1.0. Mud Pit Sample Filtrate - @ of. Drill Pipe Length 10000' 1.0. 2. 764" ppm 10020' Packer Depth(s) Ft. Mud Weight vis cp Depth Tester Valve 10003' Ft. TY'G AMOUNT217511 psi Depth Bock Surface 1/4" 1/ I' Bottom Cushion as Ft. Pres. Valve 9998 Choke - 2 Choke 5/811 - Recovered 420 Feet of Mud - gassy >:!! ?= .,(') P 85: Recovered Feet of 'TI ., 0 3 ~ Recovered Feet of ;;' ~ VI .... /1) H ., Recovered Feet of < g; 9.. < /1) Cf) Recovered Feet of I".Ej H t%j ~ Remarks t::I .- () 0 C ::I ~ FOURTH GAUGE ~ Gauge No. 2856 Gauge No. Gauge No. ~ TEMPERATURE TIME H DeDth: 10036 Ft. DeDth: Ft. DeDth: Ft. b;: 12 Hour Clock Hour Clock Hour Clock Tool AM. ~ Est. of. Blanked Off Yes Blanked Off Blanked Off Opened P,M. g Opened AM. ga Actual OF. Pressures Pressures Pressures Bypass P.M. Field Office Field Office Field Office Reported Computed Initial Hydrostatic 4558 4579 Minutes Minutes - Initial 2651 2681 - - V> +-" .... Flow 0 ~.2 Final 365 360 .... .- '" 111 u..r.I Q. Closed in 2261 2253 > ,,\) Initial 146 146 - - ~ Co Flow 219 214 0'- Final (I) u'" QJ~ ~ v.Q. Closed in 20 l.L.ÇT - -- - \)\) Initial, - - .::.2 Flow Final .{;;'" I-æ Closed in Final Hydrostatic CTE - - - ------ .--- CTE = Cha t Time Ex )ired ~ ,-tJ /1) ~ c:: /1) Z Q 3 /1) ~ /1) ZN P ~U1 '" .... Z P I-' 0 0 ~N œ 0 .... - /1) Q. 5" I .... /1) p....& ~ 0 -.p.. 0\ I-' - c:: Z H a z a H :-I ,-0 3 a III :3: 111 I\j ~~ ~ ~ ~ Qo 3 t-xj '0 g 0 '< ~ Z:-I 0 H ~ t-xj ~ Z H > FOUM t81'-PI!INT!:O IN U.S.A. FORMATION TEST DATA LITTLIt'S IH74 8M 8/73 Gauge No. Depth 10008' Clock No. 24 hour Ticket 3382 8739 No. 599127 First First Second Second I Third Third Flow Period Closed In Pressure Flow Period Closed In Pressure Flow Period Closed In Pressure I Time Defl. PSIG Time Defl. Log t + () PSIG Time Defl. PSIG Time Defl. Log t + () PSIG Time Defl. PSIG Time Defl. I Log t + () I PSIG I .000" Temp. .000" Temp. .000" Temp. .000" Temp. .000" Temp. Temp. Carr. () Carr. Carr. () Carr. Carr. .000" B Carr. 0 .000 2686 .000 I 389 .000 150 .000 220 1 .0166 2402 .0201 971 . 1005 169 .0774* 874 " 2 .0331 2100 .0402 1270 .2010 184 . 1581 1289 3 .0497 1868 . 0603 1536 . 3015 193 . 2388 1526 4 .0663 1636 .0804 1734 .4020 203 .3196 1687 5 .0829 932 . 1005 1892 .5025 213 .4003 1806 6 .0994 546 . 1206 2007 .6030 220 .4811 1902 7 . 1160 389 . 1407 2090 .5618 1981 8 ¡ . 1608 2157 .6425 2050 9 I . 1809 2210 H233 2112 ' I I 2167 Ii ' 10 . 2010 2250 .8040 I I ~I " I I 'i I I I I I 12 I I I I þ' 13 I I I 14 I 15 ! Gauge No. 2857 Depth 10012' Clock No. 6729 12 hour 0 .000 2672 I .000 371 .000 144 .000 208 t== I 1 .0337 I 2403 . 0413 889 .2057 161 . 1575* 851 21 .0674 2108 .0826 1222 . 4 113 173 . 32 18 1271 3 . 1011 1873 . 1239, 1487 .6170 183 .4862 1511 4 . 1349 I 1660 . 1652 1697 .8227 191 .6505 1672 5 . 1686 985 .2065 1866 1.028 200 : 8148 1795 6 .2023 572 . 2478 1985 1~234 208 .9792 1890 7 .2360 371 .2891 2073 (1.106 1951)oJ 'k 8 .3304 2142 1. 143 --- 9 .3717 2198 1. 308 --- 10 I . 4130 2240 1.472 I --- 11 I 1.636 --- 12 13 I I 141 I 15. I Reading Interval 5 ! 6 I 30 24 I Minutes REMARKS: * - '1 min"t-.o~ ** = On1v 162 minutes were recorded before chart time exDired. 7't \ FORM 18J-PRlt-.T<:D IN U,S.". SPECIAL PRESSU RE DATA LITTLE'S U976 SM 8173 Gauge No. 3381 First Flow Period I Time DefL PSIG 000" Temp. . Corr. Qj .000 I 2686 1 f .01661 2404 21 .0331 2103 3 .0497 1875 4 .0663 1659 5 .0329 995 6 .0994 555 ~ 1160 364 8 9 10 11 12 13 14 15 Gauge No. e I .000 !J .0333 2J .0666 31.0999 4 . 1331 I 5 . 1664 ~ . 1997 7 .2330 8 9 10 1 1 12 I -----¡ 13 ï4T i5Ï Reeding Interval REMARKS: FORM IB3-PRINTED IN U.S.". i 2856 2681 2406 2105 1862 1632 946 560 360 C) First Closed In Pressure I [ I Time Defl. La t + (J .000" 9 () .000 .0201 .0402 .0603 .0804 . 1005 . 1206 . 1407 . 1608 . 1809 .2010 Depth PSIG Temp. Corr. 364 899 1235 1495 1711 1877 1998 2086 2150 2206 2252 Depth 360 903 1237 1499 1707 1877 1995 2080 2151 2207 2253 10032' Second Flow Period Time DefJ. IPS IG .000" Temp. Corr. .000 . 1005 .2010 .3015 . 0420 .5025 .6030 10036' I .000 .2000 .4000 .6000 .8000 1.000 1. 200 150 170 182 194 201 211 219 146 165 175 185 195 204 214 10 Clock No. 8420 , I Second Closed In Pressure Time Defl. Log t + (J I .000" () I r .000 .07721* . 1577 .2383 .3188 .3993 .4799 .5604 .6409 .7215 I .8020 Clock No. .000 . 1531tk" .3128 .4725 .6322 .7919 . 9516 1.113 " (1. 197 1.271 1. 431 1.590 4485 .000 .0391 .0794 .1191 . 1588 . 1985 .2386 .2779 .3176 .3573 .3970 6 . * = 23 minutes ** = Only 180 minutes were recorded before chart time expired. 24 PSIG Temp. Corr. 219 862 1279 - 1522 - 1684 - 1804 - 1902 1980 2049 2113 2167 214 ã64 1286 1523 1685 1806 1903 1983 2017~~* --- --- --- SPECIAL PRESSURE DATA 24 hour L~};et 599127 I Third I Flow Period I Time Defl. I PSIG 000" Temp. . Corr. Third Closed In Pressure Time Defl. L t + () PSIG .000" og () Temp. Corr. . 12 hour Minutes L.ITTL.E'S 93976 SM B/73 Drill Pipe or Tubing ................ Reversing Sub ...................... Water Cushion Valve ..............., Drill Pipe ........................ Drill Collars ....................., Handling Sub & Choke Assembly. . . . . DualCIPValve """"""""'" DualCIPSampler ............,..... Hydro-Spring Tester """""""" MultipleClpsampler """"""'" fHkRsial'l J€)Îl'lt ~. .~ . ~~~.~ . . . . . . . . . . APRunningCase .....,............ Hydraulic Jar """" ......,..... VRSafetyJoint ......, ... ""'" Pressure Equalizing Crossover. . . . . . . . . Packer Assembly................... Diçtriblltnr .~~J?~~................. PackerAssembly................... FlushJointAnchor """""""'" Pressure Equalizing Tube.. """'" Blanked-Off B.T. Running Case. . . . . . . . Blanked-off B.T. D,,~C8I1ð'3 """"""""""" Anchor Pipe Safety Joint. . . . . . . . . . . . pg~kQr Â5lìQmbly . . :r.e.~l? . ~.~C;'?~~.e:~ . Distributor........................ Packer Assembly................... Anchor Pipe Safety Joint. . . . . . . . . . . . Side Wall Anchor .............,.... Drill Collars """"""""""" Ð Flush)ointAnchor.................. B Blanked-Off B.T. Running Case. . . . . . . . U Total Depth ....................... "0"'" 117-I'RINTE:D IN V.a.A. ':KET NO. 599127 0.0. I.D. LENGTH DEPTH 5" 2.25" l' 3 1/2" 2.764" 10000' 3 1/2" 2.76" 4.41' 3.87" .87" 5. 17' 9998' 3.87" .62" 5.77' 10003 ' 3.87" 4.59' 3" 10008' 3.87" 3" 4.67' 10012' 3.87" I" 3.25' 5.15" 2.4" 3. 95' 10020 ' 2.87" 2.4" . 8.76' 3.87" 3.87" 4.03' 10032' 10036' 4.08' 3.87" -- 1.04' 10041' 10461' EQUIPMENT DATA LITTLI['. L,'-- Each Horizontal Line Equal to 1000 p.s.í. """..' """",.", "-,---"--,._-~,,---~-,-,,,,,-~~'-""""-"""'-_.'~ " f .~ "\ ) ',. NOMENCLA TURE b == Approximate Radius of Investigation. . . . . . . . . . . . . . . . . . . . . . . . Feet hI == Approximate Radius of Investigation (Net Pay Zone hi) . . . . . . . . . Feet D.R.==DamageRatio """""""""""'...................- EI GO := B.T. Gauge Depth (From Surface Reference) . . . . . . . . . . . . . . . . . . . Feet h ==Elevation ..............................................Feet ==Interval Tested .........................................Feet hI ==NetPayThickness .......................................Feet K ==Permeability ...........................................md K1 == Permeability (From Net Pay Zone hI) ........................md \ nl == Slope Extrapolated Pressure Plot (Psi1/cycle Gas) . . . . . . . . . . . . . . psi/cycle OFI==MCtxirnum Indicated Flow Rate ............................MCF/D OF2=Minimurn IndicCtted Flow Rclte ............................MCF/D OFJ == TheoreticCtI Open Flow Potential with/Damage Removed Max. . . . . MCF/D OF4 == Theoretical Open Flow Potential with/Damage Removed Min. . . . . MCF/D Ps PF == Extrapolated Static Pressure ...............................Psig. == Final Flow Pressure ......................................Psig. P ot == Potentiometric. Surface (Fresh Water '1<) """"""""""" Feet Q == Average Adiusted Production Rate During Test. . . . . . . . . . . . . . . . bbls/day Q 1 == Theoretical Production w /Damage Removed. . . . . . . . . . . . . . . . . . bbls/day 09 ==Measured Gas Production Rate ............................MCF/D R ==Corrected Recovery ......................................bbls rw ==RadiusofWellBore ......................................Feet t ==Flow Time .............................................Minutes t 0 := Total Flow Time .........................................Minutes T Z == Temperature Rankine ....................................GR :=CompressibilityFactor ....................................- )J == Viscosity Gas or liquid ...................................CP Log := Co'mmon Log * Potentiometric Surface Reference to Rotary T ðble When Elevðtion Not Given, Fresh Water Corrected to IOOC) F. .r"- ,..r', Formation )~st;ng ServiC'è Report ~Œ~Œ~WŒ~ SEP 1 6 í~rl4 DiVIS10N (H' OJL AND ~AS Ar~CJi!1HAGl~ HAlllBORTON SERVICES DUNCAN, OKLAHOMA V\r FLUID SAMPLE DATA Ticket /1)/'0 7-28-74 598848 !"8 Date Number ,- - ~r Sampler Pressure P.S.J.G. at Surface ~o Kind 0 FFHalliburton un .0 Recovery: Cu. Ft. Gas of Job WATER SHUT District ANCHORAGE ,~ ;UO ::::1:1 cc. Oil '? cc. Water Tester C.H. BOATMAN Witness B. HESS cc. Mud Drilling Tot. liquid cc. Contractor KENAI DRILLING COMPANY SM -....J Gravity ° API @ OF. EQUIPMENT & H 0 L E DATA +=- Gas/Oil Ratio cu. ft ./bbl. Formation Tested ::z RESISTIVITY CHLORIDE Elevation Ft. CONTENT --I Net Productive Interval Ft. --' Recovery Water @ of. ppm ::E: All Depths Measured From Recovery Mud @ of. ppm Total Depth Ft. Recovery Mud Filtrate @ of. ppm Main Hole/Casing Size Mud Pit Sample @ of. ppm Drill Collar length- J.D. Mud Pit Sample Filtrate @ of. ppm Drill Pipe Length J.D. Packer Depth{s) Ft. Mud Weight vis cp Depth Tester Valve Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke Choke - Recovered Feet of >~ 3: "" I'D go: p Recovered Feet of "T Ò 3 Ã m Recovered Feet of ¡;i ::z VI )::a -+ I'D I-t ., < Ci) Recovered Feet of 0 )::a ;:- I'D (/) Recovered Feet of " I-t m ï Remarks Fourth gauge a - () 0 c a '< Ã rr1 ::z )::a Gauge No. 2856 Gauge No. Gauge No. I-t TEMPERATURE qq71 TIME OJ Depth: Ft. Depth: Ft. Depth: Ft. 0 12 Hour Clock Hour Clock Hour Clock Tool AM. ;0 0 Est. of. Blanked Off V~C:: Blanked Off Blanked Off Opened P.M. C (j) - Opened AM. ::r: Actua I of. Pressures Pressures Pressures Bypass P.M. Field Office Field Office Field Office Reported Computed Initial Hydrostati~ 4461 4482 Minutes Minutes -- - Initial 20{56 2056 - - V\ "U ... 'E.2 Flow 0 Final 2066 2056 ... .-'" /1) u.~ Closed in Initial - - )::> "'0"0 ï 15.2 Flow Final Þ v'" (/) cuCIJ VIa.. Closed In Ã Þ :g~ Flow Initial, - - .co... Final I-æ Closed in ~.9_I__Hydrostatic 446L-- _4-4R? - - ^ . 0 :; . 0 :Ðc:: Z. 0 3 fI) ~ ~N Z P ~ /1) ~N Z P \..0 \..0 ~O1 (1101 '" -io [ I ~--' C1) <:) ~ '" ~<:) -..I 00 - c:: z ~ <:) z :;0 ~ ~ C1) r- 0 ~ n ~ <:) ~3: ()-o 03 )::> "'Oz g -< '< zO 3 " fI) n :Þ r- 1-4 Ï <:) ;:0 Z ~ ):" rORM IOl-PRINTED IN U.S.A. FORMATION TEST DATA LITTLE'S '3974 SM 8/" VIr- FLUID SAMPLE DATA Ticket 111111 7-28-74 598848 nit) Date Number . 0 1- ~r- Sampler Pressure P.S.J.G. at Surface ,,0 Kind Halliburton 'On . 0 Recovery: Cu. Ft. Gas of Job WATER SHUT OFF District ANCHORAGE 1=. ;00 :3:3 cc. Oil ~ cc. Water Tester C. H. BOATMAN Witness B. HESS cc. Mud Drilling Tot. liquid cc. Contractor KENAI DRILLING COMPANY SM Gravity 0 API @ of. EQUIPMENT & H 0 L E DATA .....¡ Gos/Oil Ratio cu. ft./bbl. Formation Tested - .þ RESISTIVITY CHLORIDE Elevation Kelly bushing 92.6' Ft. :z CONTENT Holes at 10.006-10.0071 Net Productive Interval Ft. --' Recovery Water @ of. ppm Kelly bushing --' All Depths Measured From Recovery Mud @ of. ppm Total Depth 10 01R' PRn Ft. :E: Recovery Mud Filtrate @ of. ppm Main Hole/Casing Size 9 5/B & 7" . Mud Pit Sample @ of. ppm Drill Collar Length - 1.0. Mud Pit Sample Filtrate @ of. ppm Drill Pipe length 9 3..3.9~- J. D. 2.764" 99..55 ' Packer Depth(s) Ft. Mud Weight vis cp Depth Tester Valve 993ß' Ft. TYPE AMOUNT Depth Back Surface Bubble Bottom Cushion water 4615 Ft. Pres. Valve 99331 Choke hose Choke 5/8" - Recovered 4615 Feet of water cushion >~ s: ..~ 111 ~ P ~ Recovered 5 Feet of drillinQ fluid 'T1 ., 0 ::: 3 Recovered Feet of ~ ~ III ... ~ :.n ., < ~ Recovered Feet of 0 :( 111 ;2:! Recovered Feet of '" 0 Remorks Tool JU~fl~(.J for 04 mi nlltf-iC:: - hIJhhl~c:: tn ...1--...1 in ? minlltøc: - ,1.....-,1 fnY' rem.a i II~~~I of t:)~ t - () 0 C :3 -< ~ Z Gouge No. 3382 Gauge No. 2857 Gouge No. 3381 i-t TEMPERATURE TIME Deoth: qq41 Ft. Dcoth: QQlI.7 Ft. Deoth: aOh7 Ft. ::0 /4 Hour Clock 1 / Hour Clack /4 Hour Clock Tool A.M. :ö Est. of. Blanked Off nn Blanked Off nn Blanked Off \lac Opened e:;.nh P.M. 2 '-- 9975' v Opened A.M. ~ Actual l?n OF. Pressures Pressures P res..c;u res Bypass 7.no Pv~v Field Office Field Office Field Office Reported Computéd" Initial Hydrostatic --.4A18..- ---A4~/ 4417 ~.!15.6- f--4-4.4.2 4Llh7 Minutes Minutes '--- Initial -2il.43. 7041 ?nLlL ?()4ß ?()?7-- ?n~7 - - VI ~] Flow ... 0 Final ?nA~ -zn4~ ?nLl? ?()37' 2nhA 64 -to .-o. 204.6- 111 u.Q 0. Closed in "-0 Initial - - ~ á.2 Flow Final j; uo. IIIQ VIa. Closed in ~ - ~~ Flow Initial. - - Final ..co. I-~ - - Closed in Finol Hydrostatic 4.4-18-- ---445Z-- ---44l7- -4456-- --.-4442- --446+-- - - \ Felli'" 1Ø'--r~INTED IN U.'.A. FORMATION TEST DATA lITTLI!'!J D3!IH ðM B/u 7- C r-C ~ 0 VI III Z 0 3 111 ~~ z ? I".: ~ ~ VI ... z ? \.0 \.0 (J1 (J1 --' ¡;I a 1/1 ita 0.--1 :;00 ... 111 - ~ 9. c:: .:z I-i a .:z a I-i :;, 0 X:n 00 ~3: :3-0 ~þ ri.:z 3-< -go ~." tn 3Þ III, I-i ." a ;a :z: I-i Þ -:KET NO. O.D. I.D. LENGTH 511 2.2511 11 3~1I 2.76411 99391 3. 511 311 4.411 3.8711 .8711 5. 171 3.8711 .6211 5.771 Drill Pipe or Tubing .,.............. Reversing Sub ...................... Water Cushion Valve .,.............. Drill Pipe .............,.......... Drill Collars ...................... Handling Sub & Choke Assembly. . . . . . DualCIPValve """"""""'" DualCIPSampler ........":"......... Hydro-Spring Tester .............,.. MultipleCIPSampler ............... Extension Joint .................... APRunningCase """"""""" Hydraulic Jar ........ """""" VRSafetyJoint .....,..... ""'" Pressure Equalizing Crossover. . . . . . . . . PackerAssembly................... Perfs. Distributor........................ PackerAssembly................... FlushJointAnchor """""""'" Pressure Equalizing Tube. . . . . . . . . . . . Blanked-Off B.T. Running Case. . . . . . . II II DriliColiars ................,..... Anchor Pipe Safety Joint. . . . . . . . . . . . Temp. recorder Packer Assembly................... Distributor........................ PackerAssembly................... Anchor Pipe Safety Joint. . . . . . . . . . . . SideWall Anchor """"""""" Drill Collors ...................... Blanked-Off B.T. Running Cose . . . . . . . . TotaIDepth....................... 598848 DEPTH 3.8711 3.8711 311 3" 4.591 4.671 3.8711 -.J II --.3.25' 5.7511 '.411 --.3.951 2.87" 2.4" 8.76' 3.87" 3.87" -4. 031 4.08' 3.87" 1 .04' ,"0,.104 "7-~"INTI!:D IN V.a.A. EQUIPMENT DATA 99331 99381 99431 ~471 -.9..9 5 5 1 -9.9..671 99711 99751 LITTLE'S ...-.. I , l Each Horizontal Line Equal to 1000 p.s.i. " /"'" ',' ) ""',"" , \ ( '- .",J .. .. NOMENCLA TURE b = Approximate Radius of Investigation. . . . . . . . . . . . . . . . . . . . . . . . Feet b1 = Approximate Radius of Investigation (Net Pay Zone hl) . . . . . . . . . Feet D.R.=DamageRatio ..........................................- EI GD = B.T. Gauge Depth (From Surface Reference) . . . . . . . . . . . . . . . . . . . Feet h = Elevation ..............................................Feet = Interval Tested .........................................Feet h1 K = Net Pay Thickness .......................................Feet = Permeability ...........................................md K1 = Permeability (From Net Pay Zone hI) ........................md m = Slope Extrapolated Pressure Plot (Psi2/cycle Gas) . . . . . . . . . . . . . . psi/cycle OF1=Maximum Indicated Flow Rate ............................MCF/D OF2=Minimum Indicated Flow Rate ............................MCF/D OFJ = Theoretical Open Flow Potential with/Damage Removed Max. . . . . MCF/D OF4 = Theoretical Open Flow Potential with/Damage Removed Min. . . . . MCF/D Ps PF = Extrapolated Static Pressure ...............................Psig. = Final Flow Pressure ......................................Psig. P ot = Potentiometric Surface (Fresh Water") ...................... Feet Q = Average Adiusted Production Rate During Test. . . . . . . . . . . . . . . . bbls/day Q 1 = Theoretical Production w/Damage Removed. . . . . . . . . . . . . . . . . . bbls/day Qg = Measured Gas Production Rate ............................MCF/D R = Corrected Recovery ......................................bbls rw = Radius of Well Bore ......................................Feet t = Flow Time .............................................Minutes to = Total Flow Time .........................................Minutes T Z == Temperature Rankine ....................................oR = Compressibility Factor ....................................- p = Viscosity Gas or Liquid ...................................CP Log = Co'mmon Log * Potentiometric Surface Reference to Rotary Table When Elevation Not Given, Fresh Water Corrected to 1000 F. formation Testing Service Report ~æ~Œ~W~~ SEP 1 6 '1974 DlVlSION OF OiL AND CAS A\¡f'~.'ri)i'~1!, /"In . ~~t.~'h h'(1-"'l~, NAIll U ~ DUNCAN, OKLAHOMA FLUID Sampler Pressure Recovery: Cu. Ft. Gas cc. Oil cc. Water cc. Mud Tot. Liquid cc. Gravity Gas/Oil Ratio Recovery Water Recovery Mud Recovery Mud Filtrate Mud Pit Sample Mud Pit Sample Filtrate Mud Weight TYPE Cushion Recovered Recovered Recovered Recovered Recovered Remarks TEMPERATURE Deoth: Est. OF. Actual OF. Initiol Hydrostatic Initial Final Closed in Initial Final Closed in Initial. Final Closed in Fin~_Hydrostatic ~] Flow .- ... u.c:I Q. 1)" Õ.9 Flow u'" QIQI <no.. 1215 Flow :ë: . ¡: I-,f f'onM 181-pnINTEO IN U.S.A. AMOUNT SAMPLE RESISTIVITY Feet of Feet of Feet of Feet of Feet of @ @ @ @ @ o API @ DATA , P.S.I.G. ot Surface cu. ft./bbl. CHLORIDE CONTENT OF. OF. OF. of. OF. vis Ft. Depth Bock Pres. Valve Gauge No. Ft. DeDth: Hour Clock Pressures Field 4461 - - Office 4472 4472 Blanked Off Field Dote 7-27-74 Ticket Nwnber 598847 Kind of Job WATER SHUT OFF Halliburton ANCHORAGE District Tester MR. BOATMAN Witness MR. HESS Drilling Controctor KENAI DRILLING COMPANY DATA EQUIPMENT Formation Tested Elevation Net Productive Interval ppm All Depths Measured From ppm Total Depth ppm Main Hole/Casing Size ppm Drill Collar Length ppm Drill Pipe Length Packer Depth(s) cp Depth Tester Valve OF. Surface Choke Gauge No. Ft. Dcoth: Hour Clack Blanked Off Pressures Office Field FOURTH GAUGE Gauge No. 2856 99711 24 Blanked Off No FORMATION TEST DATA Pressures & HOLE Ft. Hour Clock Office I.D. I.D. Bottom Choke Tool Opened Opened Bypass Reported Minutes - - - - LITTLI!:'8 93974 SM 0/73 TIME BC OJ A.M. ~, P.M. g AM. g¿ P.M. Computed Minutes - - - - Ft. -I -I Ft. ~ Ft. Ft. Ft. >!! ~ 2& ? 'TI ., 0 ^ 3 rr1 ¡;f :z III :Þ ;; t-t ., < Ci> 9- :Þ ~ V> I.I'r "(1) 1"110 " 9- -Ir ~o QI"I .0 I ::t. ;:00 ::J::J 'P Ã a c: r. " 0 III " Z 0 3 (1) "'""-J I .þ :z I ~ (1) zN ? -I (1) -VI ... z ? --' 1..0 1..0 U1 U1 "T1 t-t rr1 r 0 ¡;f I III -+ 111 --' ~o ~o (1) --' <0::> 9.. - I- n 0 c ::J -+ -< -a OJ 0 ^ rr1 :z :Þ t-I f- c: ::z:: t-t a :z a t-t rl (1) £:¡ n Q a ()3: :¡: -a ~ :Þ ~z 1i-< ~o g ." -< zCÎ D :þ 3 I (1 t-t ." 0 ;0 .:z: t-t ):::> V> .... 0 .... (1 :þ r :þ V> ~ .._) Drill Pipe or Tubing ................ Reversing Sub ...................... WaterCushianValve ..............,. Drill Pipe ........................ Drill Collars ...................... Handling Sub & Choke Assembly. . . . . . DualCIPValve .......,........... DualCIPSampler ................., Hydro-Spring Tester ..............., MultipleCIPSampler ......,........ Extension Joint ..................., APRunningCase .........(2)...... HydroulicJor .....,............... VRSafetyJoint ...,....... ......, Pressure Equalizing Crossover. . . . . . . . . PackerAssembly................... Perforations Distributor........................ PackerAssembly................... FlushJointAnchor .....,........... Pressure Equalizing Tube. . . . . . . . . . . . Blanked-Off B.T. Running Case (~}... Dril/Collars """"""""""" Anchor Pipe Safety Joint. . . . . . . . . . . . Temp. Recorder Packer Assembly................... Distributor """""""""""" Packer Assembly................... Anchor Pipe Safety Joint. . . . . . . . . . . . SideWall Anchor """""'" "" Drill Collars ...................... Ð FlushJointAnchor.................. e Blanked-Off B.T. Running Case. . . . . . . . U Total Depth """"""""""'" - -:KET NO. 598847 I.D. LENGTH DEPTH 2.2511 l' 2.764" 9939' 311 4.411 .8711 5. 17 1 99331 .62" 5.771 9938 1 O.D. 5" 3,k,1I 2 3.511 3.8711 3.87" ~7" 3.87" 5.75" 2.8711 3.87" 3.87" ---.3 II 1" 2.4" 2.4" 4.591 -A.671 3.25' 3.951 8.76' " 4.031 4.081 1.041 99431 99471 9955' 99671 9971 ' 9975' 10018' PBD Each Horizontal Line Equal to 1000 p.s.i. 0 (~ -.......1 .. "NOMENCLATURE b = Approximate Radius of Investigation. . . . . . . . . . . . . . . . . . . . . . . . Feet b = Approximate Radius of Investigation (Net Pay Zone hI) . . . . . . . . . Feet D.R.=DamageRatio ..........................................- EI GO = B.T. Gauge Depth (From Surface Reference) . . . . . . . . . . . . . . . . . . . Feet h = Elevation ..............................................Feet = Interval Tested .........................................Feet hI K = Net Pay Thickness .......:...............................Feet = Permeability ...........................................md KI = Permeability (From Net Pay Zone hI) ........................md ~~ m = Slope Extrapolated Pressure Plot (Psi2/cycle Gas) . . . . . . . . . . . . . . psi/cycle OFI=Maximum Indicated Flow Rate ............................MCF/D OF2=Minimum Indicated Flow Rate ............................MCFjD OF3 = Theoretical Open Flow Potential with/Damage Removed Max. . . . . MCF/D OF4 = Theoretical Open Flow Potential with/Damage Removed Min. . . . . MCF/D Ps PF = Extrapolated Static Pressure ...............................Psig. = Final Flow Pressure ......................................Psig. P ot = Potentiometric Surface (Fresh Water *) ...................... Feet Q = Average Adjusted Production Rate During Test. . . . . . . . . . . . . . . . bbls/day Q I = Theoretical Production w jDamage Removed. . . . . . . . . . . . . . . . . . bbls/day Qg = Measured Gas Production Rate ............................MCFjD R = Corrected Recovery ......................................bbls rw = Radius of Well Bore ......................................Feet t = Flow Time .............................................Minutes to = Total Flow Time .........................................Minutes T Z == Temperature Rankine .....................................oR = Compressibility Factor ....................................- p :=Viscosity Gas or Liquid ...................................CP Log = Co'mmon Log * Potentiometric Surface Reference to Rotary Table When Elevation Not Given, Fresh Water Corrected to 100° F. ( Union Oil and Gas Division: Western Region ", Union Oil Company ( ~alifornia 909 W. 9th Avenue, AII-.;h')rage, Alaska 99501 Telephone: (907) 279-7681 rl ~1~!"'1 Lm'. '" r'.: "~ l"~! "il" ' r:'! ¡}lJ f.~¡,j ll{) ¡.,:' ~L! UU k' Dear Mr. Smith: August 13,1974 Mr. Rodney Smith Regional Oil & Gas Supv. Conservation Division U. S. Geological Survey P. O. Box 259 Anchorage, Alaska 99501 RE: KDU It 2 KU1143-6 KENAI GAS FIELD Enclosed for your files are the Sundry Notices & Reports ûn Wells (Fom. 9-331) and the Lessee's' Monthly Report of Operations (Form 9-329) for Kenai. Deep Unit #2 and Kenai Unit #43..6, Kenai Gas Field. Also enclosed are copies of the DSTfS run on KDU #2. sk Enclosures cc : Mara than Arco Socal Very truly yours, Q~R.Q¿..~ ~;~ R. Callender District Drlg. Supt. Tom ~farshall Division of Oil & Gas ~ œ ((: Œ tw fE ~ 5EP 161974 DlVISION ~F OIL AND GAS ANGØßß~~ Form 9-331 \~ray 1963) UNITED STATES SU1JMIT IN 'l'RIPI.ICATE. Form approved. (0 h I tI Budget Bureau No. 42-,RH24. DEPART~" NT OF THE INTERIOR ver~e('~IÙ\sstrtlc(o!18 on re- 5. LEASE DEs1l;ÚTIO:-I A~Si¡ï:lAL'~~ G_JLOGICAL SURVEY , -~---A-Of814_2______- 6. H' 11'11>1.-1.:-1, ALLOTTEE OR TltlBt: ~A~!E SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for propo:;;als to rldll or to deepen or plu~ buck to a different reservoir. Use "APPLICATION FOR PERMIT-" for such propo:>a!s.) 1. 7. USIT AGREE)!ENT r\A.~n: OIL 0 WELL GAS rv1 WELL L.ðJ OTHER . Kenai Unit - 8. FARM: OR LEASÊ NAM:E 2. NAME OF OPERATOR UNIQN OIL CO~IPA~~Y OF ~IA 3. ADDRESS OF OPERATOR 9. WELL NO. 909 West 9th Avenue, Anchorage, Alaska 99501 4. LOCATIO=' OF WELL (Report location clearly and In accordance with any State requlrements.- See Also space 17 below.) At suriace , t' """,, ... ~ 1").... HJ. # " ~~~C TIlt ....... 10. FIELD A~D roo , OR WILDCAT 405'5 & 4381'E from the N\'l comer. Section 7: T4N, R11W, S. M. . _-Ken~ ; r,él$ Fi e 1 c1 11. S¡¡;C., T., R., M., OR BLls;:. AND SURVEY OR A.llEA 68-49 115. ELEVATIONS (Show whether DF, RT.".CR, etc.) RT 90' ' Section 8: T4N~Jv~S 12. COUNTY OR PARISU\ J.3: STATE 'Kenai Penn. Alaska 14. PERMIT NO. 16. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPOaT OF: SHOOT OR ACIDIZE ABANDON. WATER SHUT-OFF §, FRACTURE TREATMENT - , SHOOTING on 'ACIDIZING -.., '. . REPAIRING WELL , , FRACTURE TREAT PULL OR ALTER CASI~G MULTIPLE CO~iPJ.F"l'E ALTERING CASING ABANDONMEN1'. .:" TEST WATER SHUT-OFF REPAIR WELL CHANGE PLANS (Other) , ' , (NOTE: Report re, suite; of multiple comp!etlon on Wen (Otber) ., Completion or RecoffiI2Jetioll Rep~rt a..!.l~ Log .~~)l"!Jl,) 11. DESCltIl3E PROPOSED OR CO~lrI,ETED OPERATIO:-;S (Clearly state all pertinent detnili'!, and ~ive pertinent dates, including estimated date of starting any proposed work. If well is directionally drilled. give subsurface locations and mensì¡red and true vertical depths for all markers and zones pertl- nent to this work.) . , " , " ,>, I)T ^'!\T An 'PD(\.!"T:D!!Dt':. ~'VoL ,L\.Vl..o.L...oL Ut,,",-". ", --- " .. .,~-~ , ,- ':! " .. .. '. Conmu::nced operations @ 6:01 am, 7/18/74.:; Killed well \',r/ 68# leu. ft. WO Fluid. ", . Pulled tbg. pkrs. & accessories ," ,:" ' '~', CO well to E11) @ 10,461'. ," Rigged up Go- Inter11ational & ran Dual Neutron Log from 10,300' to 9000'. Ran CBL-VD Log from 10,300' to 9000'. ,,' , 6. Drill Stem Tested the Kenai D-4 Gas Sand and D..3 Gas Sand and abandoned above sd. after determining to be non-productive. ' 7. Tested Upper Tyonek Sand from 8245' to 8255', non-productive" 'Squeezed perfs w/ 150 sXo Class uG" cmt. " Perf. Sterling Pool 6 Sand from 5235' to 5265', 5170' to 5190' and from 5128' to 5138 Treated D-2 Sand & Pool 6 C-l Sand w/ Hydroxy-Aluminum for sand control. Completed well wI dual 2 7/8" tbg. strings. tIpper completion-Sterling Pool 6 C-l Sand. Low'er completion",Deep Tyonek D...2 Sand. Wi Œ'~..,.,,¡œ..,. om. ß. Wi,' ',~' fõ1.' RIG RELEASED @ 6:00 pm, 8/20/74. lW ---~_._. - ~v~._-_-A L T ~- ä~F": 1 0 't9J4 .. 1. ? .... 3. 4. 5. > . 8. 9" 10. , " 18. I hereby ë(f'fUb;,-that-fh~C .Q'~)egOJ.Ng1S, -true and correct ~~" ~1. .':'., "~." ' -,- \l... . '/ ,", U1U..,J\ll'/, Uf Ua.l:nl~H'~~!"'~ ~-~~ t. " ~~L~tA-d,~~ ~ llis-t~ -S ~ i :ÄNta~ 9/l7 /PT {1 --~~~~~--2¡rll:.J~~,=:"-ÇãJIGÏla~=:--~"-----" TITLF~ - --. : . ~ -." .-- - "- ,. "- =.-=-~~":;!:!.=~~~== (This space for ¡i'edernl or State otfice use) : ". .Â,PPROVED BY CONDITIONS OF' APPROVAL, H!' ANY: TITJ..E DATE -"-- "," " , , *See Instructions on Reverse Side ( "J' UNITED STATES ~, DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Form aPI)ro\'e-d. Budget Bureau No. 42-R356.5. LAND OFFICE __nun_-____-------------_u_--- LEASE NUMBER __..A~_O28142.------------- UNIT ___K~n~i_P~~J~__Unit___n_n- LESSEE'S MONTHLY REPORT OF OPERATIONS '- State '_---l\la~ka__-_-------------- County --_Ke~ Penn.-------_--- Field ----Kenai-.Gasufie1dn------_--- _n_---___-__mU- The following is a correct report 01 operations and production (inclz¿ding drilling and producing wells) lor the month 01 ------------August.------______h___' 19_1A_, ,._---_---_--m___m_--_____~__m_m___--_m______---------------------- ~~:=~'- ~ _:~~~ ~~~ - -~-~-~ J!~-~-;-~-~-;-~~~-~ f~ ~~:_~?_?~~~ ::: :::=:::::: ~ ;g::: = ~ - fJ', ~,,~- ~::::: Phone - _____mm_____-.2.7_R ":_7_6.8.l__-.Ex.t.- --4. 4£"_u__m___m- _m ____om A g en t' s tCI_- R_i ~~r i~j;__D..rl g-,- -_SJ..1p_t._---- ___n_- "". . ... --- -_._--- SEC. AND "'ELL DAY8 Cu, FT, OF GAS ~ 011' U Twp. RANGE ~O. PRODUCICD BARRELS OF OIL GRAVITY (In thousands) GALLONS OF BARRELS OF HEM AHhS 0 ASOLINE \V A TER (If (If drillinll, dl"Dth: if ,hul down. cuuse; RECOVERED none, so state) dale and rr.ul~ oi !~'l'io.~ (.:-"oiine conteD t of IC,"') " . ,tiO1S on KDU #2 @ ollws: t 7/19/74. Operat ens for the month of CampI ted DST f3 0 D-4 Sdse perf from 10,028' t 10,036' &' from 0,080' to 10,092'. Perfs mad wtr. C) wI "bit to E @ 0,436'. Teperf D- Sds. f om 10,076' to 10,0 & fro 10 026' to 0,03' . Reran ST t 01 & test - d D..4 Sd.. perfs Perfs made '~i:r. Ran ~~IL-D. sit LoJ fro. 10,300' t 430'. Ran CIL..VD Log fro~1 10 300' to 5790' ~ Set cnte tete boy' D-4 perfs @ 9 50'. Set cmt. et. ahoy;. D-3 pe fs @ 9750'. Squee cd ff LweI' "DB one wI 150 sx. ~mt. Set .solation Yet. @ 290'. Perf. Uh",'p""~_""",'r",,,,",-~"""~l" <:: (~ r-"!"'.r'.~.' ,,_1::15' 1-1'"'¡ P.?~5t -f.\'r. n~T #~ 'rhm :::¡"ldl <::!'>t'.r.J'"-,'r to. no'@ .1{') 1'7', J:.l \or.&. 10]""1>,""'" v..... ...""u..... ...........- --- -..... -" .-. ~ 1"-- .-'-IJ.. '----- . Üó.,"-,' .. Perfs mad dry gas @ l.tS mmcf/d tee Pooh. Ra ¿~ set R"'-TS tool @ 81341. Purnped into I crfl@ 8 45' to 8 55' t 2 :cft @ 29)0 psi. Ircreased ress. t 3200 psi. Forma ion rek dWi. R leased R1 too & Pooh. Set emt. rete @ 185'. TIB wI rete .tinter 0 DP & st- bbed into et. Squeezed ,./150 sx "G'" em . to a final press of 3250 psi Po h. Rkm CB -VD .og from 6 00 I to 4 00' &' C \<{ell to 9744 f . Set 7' RBI@915t&RTItS@9540'.,TretedLowerl"..'D-2"Sd'..e perfs fTcm 9558' to 9588' w/ 1 dro "I" JJminthll. Attemp .ed t straddle !Perfs fr m 9510' to 9522'. UnablE to rea:dllJn "tvl f. 500 PSi.. )ooh<1 Perf uPPcP.r "D-2" ,'5, from 9510' to.. 95. 22'@ 4 hpf Set RB) @ 530' & RTI'S @ 9 80'., Treated ~t)per ItD.. tt Sds. rerfs frO!;l 9510' tc 9522' wll-ydro,- -AumÌlll . Perf f om 5 19' to 5120' for W,;O. TIB ~!/ 9 S/8n Krrs tool. RB. S - t RLP @ ...183 t . Set RTIS @ S085'. Jpened t 01 'vI 2' 00 psi. Ill! on perfs @ 5119' ,0 5 20 t ,,'Or WSO tes. W ,11 flowed @ 2 mrficf d \.¡/ 11 0 psi. surface press & n wtr Fri. I-ool 6 C-l d. f~om 5235' t 5265',5170' t 5190' and from 5128' to 5138 t t.L,de b' t & scrape, run to top of 7ft liner @ 5821'. Ra:n 9 5/8" HBP & RTT~ to . 'et LBP @ 5300 f 0 Se RTf, @ S090' e Treated perf sd. . wI Hydroxy- Alunùrum. Ran hL :unk asket & gage T. ng to 9600t. Set lcrm. pk . on KL @ 9500' 0 Ran, [, 1. and~d d '.:d. 71, 8~ tbg. ~s p "ogr~J,¡cd. Insta, led. BPV . ReDìOV - BOPl,:'" , ' ~nsta,-" lle( x-mas tree ¡¡ tstc' to loaD psI-ok Dl'Pl. salt 1>tr. m a nUh!È ~ rU'w1tr1m 5fi-. 1 ð 197A . '. - ~JaL- ANGHOBAGf!. N oTJ<J.-There were m-___n_n___m___m____---------- runs or sales of oil; ____nm--_-____m_-----____nm-m--n--- M Cl1. ft. of gas soh, ------------------------------_____um----- runs or sales of gasoline during the month. (\Vrit:e "no" where applicable,) N()'f}o;.-H.eport on this form is required for each ealcnd¡_tr month, regardlcs:,; of the status of operations, Rnd Inll:;;f:, be iiJcd i duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supcrvi~or, l"orJu 9~~Zf' (Janut>ry 1\);",0) 892.556 U.S. GOVERNMENT PRINTING e>fFICE :,1961--o-nrt--ï84 \ '< ¡. " ~..fó, . I J: ffù æ n WI fÇ laPtll'OVedo ¡ , ,i" UD '¡¡; 1l.v.\11 ~ . t Bu~u No. 42-R366.6. UNITED STATE 0 E __h_--___u---------_u_--- DEPARTMENT OF THE I ',' 1~~6 5~~N~.M,9 .-_:-_O_~_8.1A!~-r.----------' GEOLOGICAL SURVEY 1 UIID'L~~Qnal._D.~ç¡l_,_ll.._t._.--._-- , ",' DIVIJWN _Of...DlL. 'AND 'C,l~ ' LESSEE'S MONTHLY REPORT QFAWfllRUilcmS ( State _---__n~!~:>'~nn__n__---- County -~~~~!_-~~~_~~___n___'--_- Field -_!i.~!:~-~--_CJ.~-~-_E.~-~_!_~- ---- --~ - - -- - ~ - -------. ____n_-__- The followin~ is a correct report of operations and production (includinst drillin~ and prodllcinfJ wells) for the month 01 n__u_n_m---J111Y----___----------1 19 _2..4_1 ,.,.n_--n_------_d_____n______---____-_n-n_--____------_-_--um__n__- , I 90° 1" 0 J 1\... rr ~TIOJ:~;;!,1& Cn'(f')'\rv ('\T~ (' \1 T" .d.~ent s address -_on ;t-- \est--..;.t ~-..J~, .enue--_n_------------____~ompany - - :~~ ¿¿oj v l....:.........:..\...:..J.._- ....:--1.--_~_i__. n__.___n--_____-______m____.An.çhQr.a.,g.c..._J...\la£k~L_____~_5_Ql~--___n--_- Si~ned -- -- - - n-_~- --~Jr.4__----5.!~--:_. Phone --------___"__n_____2_Z~:-}JlS_l__--[;xt.._-_4.4.S____nn___-------__-_--n .d. ~ent, 8 ' i tle _n__--J)j._~_trJf_t_Dx.tz ~---~:~~~ t ~------ -' ,.. '.._-,- SEC.,A.ND WELL DATS 0 G Cu. FT. or GAS . K()'~ Twp. RANGE "~O.PRODt1CI:D BARRELS OJ' XL, IU,VITY (In thOUS<U1ds) GALLONS OF BARRELS OF RE~fA H KS GASOLINE \V ATER (If (If drilling. d"p:b; if .¡"" down. èl\\~'e; RECO"EREì> none, so state) date and r""'lIll,()f \"~l I", ¡....,,¡¡ue content ofll!1j\j , TTh' l' if u,¡,¡ "j --- Cornm ¡lced ope ati s of KOU #2 @ :01' '-:1, 7/19!74 Opera ions for tLe nort~)of July t.re S £110\\$: IClled'velll\I/ 6 if, 5% KCL. Renlove' x-mas t'ce f¡ hlstQlled BOPE fte ted to l - COs )ecs. lÌlled 3 1/2" tbg. trìng & hyd. pkr @ 9819 t {~ 9..1 Œì' . CO 'ln esg to ETD (9 10, 61'. Ran Dual :~eutron Lo:> fror.} Ie ,300' to 000' & £0110v(;r1 wI C 1,.-VD Log eve same interval, Per., for '\~tr« shut-o£~ test fr.m 10, OO{j' to 10, n Set itt. et. @ l'"Q18' Dry,t~sed.pfs. @ 10,06' to 0,007' w DST #lw/no fluiden:t y. Mil d ov rBaker t. r t. @ 10,01 P w/ fu 1 reGave /. Perf.~. hpf "£',.,','"",,)9",1,",,9" t ('9""C'~" ,,',1, ,','t"". ,tt,9{gr"o'. 't 't' '" ,'("" ç {,(,,~O', """",)..,. ,f .rorn 'J,' ~ 0 J.t' an, se em. e. t:! ", ~ ;. 1 :este<.. perrs e J.1J.~'¡ to ~}~¡.:.¡.!' \"1 R§Ttoli'2w 110~luid,clltry. .' R set, 31 tool@ ,,879' anc tested, Toductìon T,1erfs. from 884 to 991'.P ~rfsmadê XT. ¿; loaded Dr (killed Hel1}.B ) yet. @ 9950' & pushe to 10, 98'. Set isolation rete @ 9S79' be "Ween D- product on perfs @ 9884' to' 910 & 0 .d DS perfs IT III gat' to 9874. Set ¡ U RTI'S tol@ 9822' (¡ well rod' cod dry .;as@ low ratev/ no vtr. entry Pooh II DST. >0 cmt. rete @ 937 ' ¿~ Poo]. Ilsta1 ed predue'ion stsepera or to J)~ T D-4 Sd perfs frO1~ 10,02 to 10 036 an fro 10, )80' to 10 092'. TIB,.;! D T#3. Now: D... 4 Sand Perf. ---- N O'1'E.-There were --------u-----------_u____--_n___urun.s .or sales .of .oil; -------------..---------.._u-'----_u_---------- M C\¡. ft. of gtì8 s.ol, -_u_",---..-.--......----------u_---___u-_mu runs .or sales .of gasoline during the In.onth. (Write "no" where applicable,) Na1'E.-Report .on this form is required for each calendar m.onth, regardlQss of the status .of operations,and must befik:d duplicate with the supervis.or by the 6th .of the succeeding m.onth, unless .otherwise directed by the sup~rvjsol'o Fonn 9.:~29 892.556 U.S. GOVERNMENT PRINTING OfFlCE;1g6~--o'?29"la, (JanUllrY1950) '. Fol"~. 9-331 )L¡y 1963) UNITED STATES DEPART~( 'T OF THE INTERIOR Go ...JLOGICAL SURVEY SUNDRY NOTiCES AND REPORTS ON WELLS (Do not use tbl~ fNm !l)r propos:!]!; to dr\1l or to d~ep('n or plu~ back to a dit!erent reservoir. Use "APPLICATION FOR PERMIT-" for such propa:sa.!s.) srBMIT IN TRIPLICATE- Form approved. (Other instruct('.- cn re-- B~l_~_~~.~~ureau :No. -t~-RHZ4. VE.'rse side) 5. LEASE DESIG:-;ATIõ~ ,\iiÕ'-S~-RÙî:~-~O.-' .\-023142 6. IE' INDIAS. ALLOTTEE OR TlllBE ~A~IE 1. 1. UNIT AGREE)IENT NA)IE OIL 0 WELL (a s f\T1. W'ELL ~ OTRER " '~: I-'"'T' :l i T 'n -1 t 8. FAR~ OR LEASE NAMIt 2. NAME OF OPERATOR lliIO~'; OIL CCY-LPAi,Y OF CALIFO~HA 3. ADDRESS OF OPERATOR ,. 9. WELL NO. 909 i\;est 9th Avenue, Anchorage, l\laska 99501 4. LOCATIO:\' OF WELL (Report location clearly and in accordanc(' with any State requirements.8 See also spact> 17 bE.':Ow.) At surface 40S'S & 4381'[ from the N1'; comCT. Section 7: T4;~, PJ.!;';, S. I.I. ~(('.nai neeD I TL it!: 2 10. FIELD A:\n POOL, OR WILDCAT ~(cn~d C~15 fie: lc1 11. SEC., T., R., M., OR BLK. AND SURVIDY OR AREA 68-49 I 15. ELEVATIONS (Show whether DF, RT, GR, etc.) I RT 90 ' .. C" ti S. 1'4' ',' Dl11'T (' ,,)ec~on~,. <'o, \.- ..,,' ;,12'.,CO..UN. TY..OR PARISH I 13, STATE .1"'e~,..,i 1":'I!"1'l "'l'lC"a '".,0,- \..-'.. J',<-'j,c. 14. PEn:'UT NO. 16. Check Approprìate Box To Indicate Nature of Notice, Report, or Other Data NOTIcm OF INTENTION TO: SHOOT OR ACIDIZE :.'>IULTIPLE COMPLETE ABANDON. SUBSEQumNT REPORT OF: WATE' 880'-000 It. .E..m'G ,WELL FRACTURE TREATMENT ALTERING CASI~G SHOOTING 011 ACIDIZING - ABAXDONMENT* TEST WATER SHUT-oFF FRACTURE TREAT PULL OR ALTER CASI~G REPAIR WELL CHANGE PLANS X. (Other) , 'hc' 1 1 (NOTE: Report resu1t3 of multiple completion on Well (Other) ...,ec Je 0\11 Completion or Recompletion Report a~~~ Log form.) , 17, D~;SCRlm~ !'[tOPOSF:D OR CO)! PUT ED OI'ERATro:\S (Cle:lI'Jy state 1111 pf'rtint>ut details. and give pertinent dates. including estimated dn te of starting any proposed work, If well is directionally drilled. give subsurface locations and mE.'as\1red and true vertical depths for all markers AIld I':ones perti- nent to this work.) . , ,.." "" """::,, j\rncndcd Plan of Procedure to include: .. :;: '.. "',' ':'" ", ,; , ... , ", " .., 1. Aband011 Lower' tJ)' t Zone: D-3 perfs 9834'-9910' (wet) ,; '.. " D-4 perfs 10,026'-10,038' (non~rro,l,uctive) D-4 perfs 10,076'-10,094' (non-product,j:vc) ,,;' , " ., ~~ -, ' by setting isolation rete above D-4 @ 9950' G 2nd rete @"'9750t:~Snueeze , 150 sx. Class "G" CJ~lt. below ret. @ 9750'. (lliscussed verbally i\T/ :-Zodncy" Sl'1ith, US(~S Regional Oil G Gas Supervisor, 8/7/74). ((:..:':::--';: .. ~~:'. :~ .." :';, Squeeze off \\r/ ,~)50 ,.sx. Class "GI! C" "i:' ", .. ,: 2. Test Upper Tyonck Sd. from 8245' to 8255'. 01lt., if non-productive or \vtr. ,~ " .. ,;, " " 3. Perf. Sterling Pool 6 Sds. from 5128' to 5138', 5170' to S¡gO!~nd fTO!~ 5235' , , to 5265'. '-,: ,) ,,' ", ~/ :; -; " 4. , '. ,., " Treat thcD-2 Sds. 4 Poo16 Sds. 'ý/ l1ydroxy-Aluminlffi1 for sand control. , , s. Complete '¡,veIl w/ dual 2 7/8" tbg. strings in Sterling Pool ,':6'~ Deep Tym)C\,k D-2 Sds. -----J~.. , I 18. I hereby cer'~.ifY t,hat the ft>rego~~~»>~u~ ~d corre~t ,:, ,., ~", , -~/'~¿ti;~~~~~~=== (This '-špace for 1,<"ederal or tate offi Ise) . , , .. ,'. APPROVED BY _.. CONDITIONS OP TITLE ~ " DATE ~ :,,' ,', *See Instructions on Reverse Side !, ~"~" ""-,', , rOV8,d CO,'PY. ' t:biJJ.J~ ,", "'"':'q...;,,~,,,,;,,:!1'" ~ . Form 9-331 (~!ay IDI;;q ,UNITED STATES Sl'BMIT IN THIP1,ICATE. Form approved. (00 ! t . -----, Hudg'E't HUrE'3.11 ~". 42,--R142-i. DEPAR( -;ENT OF THE INTERIOR "~'rs~.l'~idel)s~) ¡Ollti on r~ :J. LEAS1!:-DESIGÚTlO~'~~~[;sì.:iÚÃL--Nci:-' GEOLOGICAL SURVEY -i\:-_O2lli2._____-- 6. U' INDIAN, ALLOTT¡';¡; OR TRIBE ~A:'>E SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this (!'Tin (or pr()r\)~,d;; tt' drill or to dpepf'n or plu~ back to a different reservoir. Use "A:PPLICATlO;"¡- FOR PER~1IT-" for such propo;¡a]s.) 1. 7. t:NIT AG'RI:E:'>I¡¡;ST ~.\:In; OIL 0 WELL GAS fVl "ELL l/).J OT" ER Ken.:Ji-.Lh1 it 8. FAR:'>! OR LEo"S1\. SAME 2. !'A!>IE OF OPERATOR UNION OIL CQ\IPANY OF CALIFOHNIA ~ADDRESS OF OPERATOR 9. WELL NO. 2Q~__1\.est 9t!~_Ayenue, An~horage, Alaska 995Q1 4. LOCATIO:'; OF \\'~;LL (Rf'port location clearly and in accordanct> with any State requirements.. See also spact' 17 below.) At surface __~~na ~,J)g,~LJlDj_~_! 2 1-~. 10. S'IELD AXD POOL, OR WILDCAT Kenai ~ Fi~lc1 T~eJ. 11. SI::C., T., R., !d.. OR BLK. A~D suan¡y OR A 11.& A 405'S & 438l'E from the NN corner. Section 7: T4N, RIlW, S. },1. Sec. 8: T4N, Rllì\;, S.] 12. COUNTY OR l'A. &[311113. STATE Kenai Penn. Alaska 14. PER:lIlT NO. 68-49 115. ELEVATIONS (Show whether DF, RT, GR, etc.) RT 90' 16. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: . TEST WATER SHUT-OFF WATER SHUT-OFF § . . FRACTURE TREATMENT' SHOOTING OR ACIDIZING - ALTERING CASISG ABANDON:lIE~T. PCLL OR ALTER CASI:'iG REPAIRING WELL FRACTURE TREAT ~IULTIPLE CO:lIPJ.ETE ABANDON" SHOOT OR ACIDIZE (Other) (NOTE: Report results ot multiple completion on 'VeIl Completion or ~~~c°!Dpl€tion Report Rn~ L°IE._!orm.) ---- 11. DESCRIßE 1'1\01'08.;0 OR CO~(I'LEn;D OPERATIO:';S (Cleal'ly state all pertinent details, and ~ive pertinent date!'\, including estimated date of starting any proposed work. If well is directionally drilled, give subsurface locations and mellsììred and true vertical depths for all n1:ukers and 7,oues perti- nent to this work.) ... , RE:PAIR WELL (Other) *See Below CHANGE PLANs *To determine source of w"tr.. production & shut-off \'Jtr" entry. ..,,' ... PLAN OF PROCEDURE: .¡ .' '. .._, " 1. 2. 3. Rig up over well. Kill well wi 70#/ cu. ft. KCL salt ~~r. Remove x-mas tree. Nipple up & test BOPE. Release single hydraulic pkT. @ 9409' & 9818'. tbg. string. CO 9 sian esg, to Run Gamma Ray Log 9818' . Ont. squeeze wtr. entry as determined from Gal1Ul1a Ray Log..-. CO 7" liner to IO,477'ETD. .- Complete well w/ single 3 1/2" tbg. string & return well ~o production,. .. '. - -.'. .: : 4. 5. Pull & lay dwn. si.!1g1e 3 1/2" top of 7" liner @ 5821'. CO 7" liner from S821' to lO,.477'ETD. & determine the source of ,'Jtr. production entering frOJTì beloH -. 6. 7. 8. ESTIHATED RIG OPEHATING TIÌ\IE: ~ ~ -- , ~..~.~ ~ü,~ffi ~ , , : IU;Î\~ ").. ~1\J74 " ., . V ,J .'-... - ' ...J I.', Fourteen (14) ÜIVISHH~' Or OU~ Af~Ð GAS 18.-1 herëbŸ-(~...iJifY. thãT""t~~!.~1eg~Iig'.IS. ,.ti-l.~.cand co~~rect . .:' ..: .. PJí,CHmi~AGÆ., ,).,J"'-7'"r') / C. C /. 1"('",- . [ ". .. SIG~E9;ì~ttLztle~d~~--~~-"~-( ~ C/---TiTLE __Dist. Drlg.. S1 1pt+- DA'l'ID -5l1!JI-J.Jt------_. =.t:~",-===c,..::::,~o,.,:--":c...::..:...:.c:.::...:.:c:_--..::=..:.:..."-,,,,,,--,:.:.:=~-.-,.,--... .-.,--- .__. .---..-..,- --_.,-,. -~._--..._.._- ----- -----,- --.--..---------.---"'=,-....-'--'-.---;-..--- ---...:::::..=c::.:::::= ~ ::: ;::: '~: 7 Z;7~ TITLE . DATE -1 ~ 1 Û ~ zL- CONDITIONS OF' APl'ltOV AL, !Ð' ANY: - . ~,:';' :~:. '.þ-'.:,p.'.pr?v.ed '.C. O.~...y.... ," .: ,R,f~rne{J' ,~, .,%'i'fo-J'l~ 7.1, ~ l' , , *S~e Insfrudions on Reverse Side ~ j- ( KL'~\I C:\S Fll:Ij) - \'.11.1.. P ìJ)lJ !i2. ri~FSr~;r ~l p;~n;'nsrD C~:'}L~:Trc',\ .'-- ~ ( L~------SSI 20" ccnductor. 00 00 00 00 - - 00 - - - 1317 t 13 3/ 8" 54. 5 f:L SIC c s g . ,. ~ æ ~, ~ ~ .!,Œ m IUr,.! ~\ '¡,-<¡Ll V ¡. V td., -------------00--5821' 7" TIhT Hanger. D1V[S¡~nN CH;' OIL ANn) ~!:;~.~.~ I' !', !~T"'j' ":' n¡ 1\ ð"ij "~"~ jl ~, ,',"', \ ¡I, [,," (I\'II",',!' . ,"",'", !,""..., ,,"-' """" I L_--_00_-_00----6O2G' 9 5/3" 40# N-80 Scal1ock csg. -------------------9373' 3 1/2" "XO" sleeve. - ,/1 f~,','~, ----,---------------9409' 6J ,/'--' t-..~.__.... Oo~.... --------_..__..-~----9447' 11,',:, -1r, .. -.. - - .. - .. - - - .. - - .. - .. - - -) " I: ! ~;. ' ° ¡i . _[1_- ------~---..-oo"""--" -1-- --------------------1 * L .. fi '; '1 ¡ ¡ ! ,ì , ; 1,1 I:p'i .~.- - ,~ ...... -.... - - - .... -.. ...... -..- ~--~ J .. - - - .. .. .. -.. - - .. - - - - .. - - - - - 9 7 8 2 ' ::-' t__..,. .. .. - .. - - - - - - .. - - - - - - - - 9 S 18 ' '\o/i "",ll /\c ,. '" , -..-" , r--"'~ :='}. - - L .. .. - - - -' - 00 - - - - .. - - - - - .. 9 8 2 5 f l-,t I -~ r , :-:::::J- - - - - - - - - -.. - - .. - .... -.. - - -.. 98 ~g IIyd. pkr. 3 1/2" "XO" sleeve. 9483' .. 9523' Blast Jts. 9554' .. 9594' Blast Jts. 3 1/2" ,"XO" sleeve. l1yd. pl~r. 3 1/2" "Q" Nipple. 3 1/2" Shear Sub. --, , - - -. - - - - - - - - - .. - - - - _1 Of)? 2' 7" 2<), /1 \1. ()' ,0 !)llt t "r-C' C" e C S. (f ....."." -. ,......, " , ., ( ", l 0.'.' ", (f. , .' ì (, PRESF>rr ~~ PI~Îp('~~rn Pì ::~F¡)R \TI(ì" .~ . r A -- <" .. '-.:n , :.: .. ',Ú ... I"':"l;I'T'l~~ r 4\' ..\..:\. ,,-.,... FCXJi'AGE .. D-2 D-2 9510'-9522' 9' 5"8' O~f"!)t ~ -;J,JÙÖ "12' . 30' . qzr Upper Zone isolationpkr. @ 9813'. D-3 D-4 D-4 9884'-9910' . lOJO23'-lG~O26f 10 080'-10092' J J 26' 8' 12' 4GT Lo\.¡cr Zone isolation pl~r. @ 9818 t 9800'-9812' 12' DST, If 1 -Open but not product i'vc . .' fÐ),", IE,', .'~...'. ~...'. ß..~..'.'...IE.lDJ ..~ JUN.5 1974 D\VISION OF OlLANDGAS , . ANCHORAGE m . ~~ -'d!I1 r'.' 0 ",,'- ' -.- , . ...' "'.. - , # ........... V -....--- r ... ... - "a- ': '. t., "" -' . "'--, " ( , . (' D JE: TQJ ~ -r~ YlT' lLQ .~ JJ. Uj llQ Jl , . .. , , and . " ~ '- "'\ ' , - or J J f ~ f> , " ~. ~, , ., PUN of §1UJR..§1UJÆJF A CJE ° §lURVJEY .' UU\ßüOU\3 ö~l ~O~~~~~V ~~[E~£~ [D[ErE~ U~ ~r ~~ ~ ( . ~~~l~ ?(g~~~~V [8)[Eb\~~o ~l~~~~A 'í'~~ r'" ,',"" ?'",',' ¡',I "I I,:' ..' ","'" lilj,~( ,1..""",N, '"",, ,,-,' """ I,: ", '¡"" f ,! ','( :\ I. 11 t, V ~I il'l , " """, \, "..,," JOB NO. ~~',':~ :,1 I.: ,:'; '~,O,'I i ",\;1 ,,;. I,:. 1".1, ¡ JUL ~ 1968 ~)¡\nSfOH OF em A.ND GA~) DATE ANCHOHAGh r; n rlLTf l11'Ttf1 ff~ t\'Yrt1.I) n1f 61'71 11 r~ n n fl11.IT ft! m tlL~E: llilll~l!1 lJUJ1~ !t,~~111 ()ljillrvtlIi Ji li\VN ' LOr¡Q BEACII. CAUrORNlA . .....--.. ,-.-..----. -- '"'- ------ ....,,",' "_"'-""4______----- ....,,-... -- ....., .."'......--.....-........."""'------.......------,....---.....,---------".--------.,--,'" , . þ ~... ,,>- I. ~ DRILLING CONTnOL CORP. '~\ \ SURVEY DATA SImET DâlLCON . ~\ I COMPANV Union 911 Cœmany DATE JUlY._1~68 f nHEET NO.__- 1. JOB NO._- WELL Ke!}ai DeeD Unit #2 FIELD Kenai Gas Field COUNTY. STATE ___]\¡ask~ I I I MEASURED TRUE DEVIATION DRIFT RECTANGULAR COORDINATES DRIFT DEPTH ANGLE VERTICAL COURSE DIRECTION DEPTH NORTH soum EAST VIr_f)' .-- 189 0° 45' 188 98 2 47 N 45° W 1 74 321 1° 00' 320 96 2 31 1'1 20° N 3 91 386 0° 30' 385 9f1 57 N 65° E 4 15 477 1° 30' 476 93 2 38 S 40° E 2 33 539 5° 00' 538 69 5 40 S 50° E ' 14 3 66 -'- 601 8° 00' 600 09 8 63 S 65° F. , \ 4 ï9 11 4r. 663 10° Oot 661 15 10 77 S .810 E G 47 22 1¿ -. -.,.. 10° 30' 722 11 11 30 S 82° F. 8 04 3.3 3J. i¿J 818 12° 15' 812 99 19 73 S 83° 'E 10 45 52 8:J 971 11° 30' 962 92 30 51 S 81° E 15 22 83 0'" L.' 1030 . 13 ° 45' 1020 23 14 02 S 87° E 15 95 97 02 1091 150 00' 1079 15 15 79 S 880 F 16 50 112 80 1185 17° 30' 1168 80 28 27 S 8So E . 17 49 141 05 , 3~'" 22° Of)' 1298 61 52 44 EAST 17 49 193 49 .L ¿'J 1459 27° 00' 1418 00 60 84 S 89° E 18 55 254 32 , 1 h' 3 3~0 30' 1549 30 80 46 N 89° F. 17 14 :34 77 .....~.l. '-'.16 32° 45~ 1661 15 71 95 N 88° F. 14 63 406 6B ..L/~ 1928 33° CO' 1813 79 99 12 N R8° E 11 17 505 7.1 2183 33 ° 1'115' 2027 05 139 82 N ~8° E 6 29 645 4~ 2410 3:° 4tj' 2215 80 126 12 N RAo E ] 89 771 52 :'722 ]4~ 0(')' 2474 45 174 47 FAC;1' 1 R9 9~5 9C) \ :::51 "',.,0 J"" 2755 48 189 57 N 890 E 1 42 11.15 53 i ;,-! \ v I .., -...,- 1:n I';' 3023 30 182 35' N 89° F. 4 61 1317 85 ;. ..::;:> -¿ -1 . t =,. ;-- ::. c\ -,'0 -(\1 3274 65 172 75 1-1 88° E 10 fi4 1490 50 I ......<~ -,'J I ~~3R 34° Je' 3561 44 197 11 N 88° E 17 52 1687 48 ( ! I ---------- '-'--'---- ßEMARK.51 -, I. ~ T 74 ~I ~{ < t1b ~" --I . I' I ' I I r' I I ~ & . _.-._.~-- ------, ~ ~. -. ---~-._---.--_._..-.----- ------.--- ------'-- COMPANY l~Jon OjJuCŒJ)-.ßn~ DRILLING CONTROL CORP. SURVEY DATA f3~ET ;,.. ,..-, . =' - '--~'----" -- ....-,. .-..... ." .-.., '- ,- -. - .- ------.c.-- 8HEET NO. ..') ... DATE J'"ly lq68 JOB NO. TRUE VERTICAL DEPTH 3749 17 3969 15 4193 87 4461 76 4746 35 . 5093 90 5433 97 5867 84 6313 74 6695 97 7083 04 7"/47 64 8058 48 "- - 8ó46 48 ('9113' 20 .' ¡ \92881°9 9897 72 CLOS "/0 - C:') ~ ê '... ---z J'; y. /5 "'-~ 6c>V DEVIA TION COURSE 112 79 114 SO 100 05 100 16 88 36 89 89 73 84 - 84 33 60 70 36 79 27 08 23 21 9 49 5 12 16 30-' 6111 21 29 . J 2644174' - WELL- Kendi _.D£ep_IJnit #2,- FIELD Ken;:d Gð~ Fip.1a COUNTY. MEASURED DEPTH 4257 4505 t,7~J. 5D37 Sl35 5694 h,j-12 6484 E934 7318 """"'6 I í" r, ., .... , b u.... RC82 9270 9737 9912 10,522 ('-, \ [ 5-'-' (':. " DRIFT ANGLE 31° 00' 27° 3D' 24° 00' ?OO 30' 17° 15' 14° "30' 12° 15' 11° 00' 7° 45' 5° 30' ~o 00' 2~ on' 1° 4~jt 0° 30' 2° 00' 2° 00' 2° 00' r-f--- ...:... 6 r-, .-.-- 0 -'.......:- if 6" .,' ... - c. STATE -dA1li~ki"' -- DRIFT DIRECTION REeT AN GULAR coo RDIN Ã rES - -- -- - . T HE:A F.KS I NORTH I SOUTH I EAST I WEST I -~. : r S 89° E S88° E S 86° E S 83° E S.83° E 15 55 11 55 4 57 S 79Q E S 79° E S 78° E S 77° E S 70° E S 69° E S 69° E* S 69° E;~ S 69° E)'( S 69° E'¡c S 69° E* S 69° E* S 87° 08' E 7164 18 40 35 55 49 64 67 17 80 83 93141 103 12 111 44 114 84 116 68 122 52 124171 132 34 18002G 191L1 69 2014 50 2113 91 2201 61 22891[>4 2362,32 :;;444 80 2503 94 "'538 r:1 /.. .) ,¿. 2563 or} r~ [- R 5 4 (' """:.:> - 0 2594 32 f 2599 10 2614 32 T};('~(> ; j r,?r<,~("rs r C'.i c: :r ' roT"'. ï70ó' 262°1°2 2639 90 . ',j 1 ~ ~:, Union Oil Compan~ ~alifornia 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 Telephone (907) 277-1401 un.en HLB TRM ~ OKO tl~ ~é "~. KL V ~-- HWI< <. ' REl - ~" - lè~ - -'" l-1ay .15, 1969 - ." FlU: ~ . - - ~ Mr. Thomas R. Marshall, Jr. State Petroleum Supervisor Division of Mines and Minerals 3001 Porcupine Drive Anchorage, Alaska Dear Mr. Marshall: Enclosed is a pressure survey for Kenai Deep Unit Well No.2 (lower perforations), Kenai Gas Field, Soldotna, Alaska. The surveys should be self-explanatory; however, if you have any questions, please feel free to call. ,you"rs very tr/, ,UljJ , 0/ f~ tZ ;:urCh . Production Engineer ~JEC :mgl Enclosures cc: R. C. Hartmann J. P. Pedretti RECEIVED MAY 16 19RQ DIVISION OF OIL AND GAS ANCHORAGE FORM 401-ANC-W (8/67) '", 'WI'RE. LINE . SERVI.C.E \'" ' E. G. MYERS ( / WIRE LINE SERVICE " -..' , . t' , ;~" P.o. Box 57 , Kenai, Alaska 283.7819 SUBSURFACE SURVEY 99611 ~ \~ . ,.~, OWNER UNION~~1_ÇO. ----_____.£IEL,I?__Ke_Dai_.Q!L~LFi~lcl_____,_~~LL NA~_KJLJLß:2 , . CASING 7','__.----.-...L------------ ,---~______E_LEV_._-_..__...__. -......-.. ------..--------- -. --- DAT~____5~_~-:65L.__.._- UNER DE~CRIPTION Perfs. 9R84' - 1 ~O92 . -----------_..---,-- ---- ZERO POINT 12' -.-- ---- . . ---------------'------______m.__-__--- ~E~!_~__....lQ...Q.20 . TUBING DETAIL 3~". otis xo~l~~ye 9374:~xo s1~eY.E?_24:4R ~.J._xo sl~~ye z£I~~Middle Kenai ~Dß 9782'. otis Q nipple 9825'. end of tubinw..858' 8______-..--------------..-- - ...--- ;: ' ! ,':, ..-_..--- ----.---------.., .,..----.------"-- .. ..--------.-..-..------- -'.---- --..-.---. Static g:r:ad ient__~:!rJ'-~_..__.._-~-:--~--,-_.:-_--------_....-c-----'-_'_- _d______'--- F>lJRF>OSE - REMARKS ---.._- ,--------,---- ELEMENT ' 420Q1t____~ERIAL N~~ÿ¡õ2---~-~-;i~~_~=-=-=j=~?~~-;~~~-----'- ~:- --,------,- ENGAGE STYLUS 9145 p. m.t. DISENGAGE STYLUS 12: Ol..§._, n~!...._2:-9-¡).2- . - ----------------- 09S. TBG. PRESS. . 1050/l.__- 09S. CSG. PRESS. ---------._---,-----_...~- ...-. ..-..----------- 1063/ '. COR. CSG. PRESS.. ' PICKUP l") 10.050' . TIME ON BOTTOM 10: 10 -P.!.!!!L_- MAX~~~~~~--_=i5.j6=:_~=.~'..=-~-~-=----_.~ WELL STATUS Stat;1£_- . SHUT IN 9 ~ 30 . a . m. . ~ , ---1 COR. TBG. PRESS. --- , , --_.---._------' -----'-'."--- STAI3ILIZATION PERIOD , . 0_.- .--.....----------- ----..--- ON PRODUCTION GROSS OIL RATE B/D ------"'----'----"- -- ...- ....-----..--. ------ TIME DEPTH DEFL. P-T GRAD. '6/D -'-. "" - -=.:_..... --=""--:=~--:--==.::-..- TIME DEPTH DEFL. P-T GRAD. 6/°- . '..' .' '. -- -.:. ',:.'~ ":' ---- -'"---"--' ----- ~E:r..,?IL_R!TE__B/D ----- !:.OR~ATlON GAS MCF/D__-- GOR cn/BBL -_........ --..-------------.-.---- CIRCULATED GAS MCF/D . ) -'-'- , _. -- OIL DRY GRAVITY °API . .' --- "C. .-------. --- "-----. "'.' ~.~~ PRESSU~.E TUB ING PRESSURE -- .... .._--- j 1 ~ BEAN SIZE ----- ._--_.~ .' ,:1 '~~I__.__=-}¡..~ --"--- .. ' . '.' " t- '. -'---- ~--==t ------+----~1--- . 10.000_" 17..6 226 0 ------' -i--.'~-;-'_:_-¡-~ 29.5Q_-=i' 93?~~6 7.1, 120 ~ -"--'--"j"'---'T'---- 9900 Q2r'76 l' 1080 .' " -;';', ""7' -;----~i'-.'---':"'-'11---J 2B..iQ~ ,.()2_26- J"?_Q2 ..980 : .'.', I,," -~~~_."'~'+.---I--'---~ 2.800 .'. _9116.__:. JZQ.5_...- ~L... t--+-1225~_~ lZ9..L 10<2- '-:-.--r----~¡-----¡ 22.0.0 ,.o26~1J69_~ -. 066 ,.__._'--~.._- I.-+--~---¡---l 20110- 8J21..JJQ52 - I .067 ' 1" .-;--.i----=.J 7..50Q__- ~87? 1 Co} 062- '. ~=:=-:j~-:'-=1--- -] ~~t~9~~~ ~~iï' . ~~~ ,- "cc--:k-t'.~~~r ~~:- j f~gg---tìt9k J~~ç- &7~ , -+-~l.J1=,-,",-",~,[,.._-.-",o,:-,':",",-j1 ~!~~=,-,-:,-:,,:J, :Q~=~,~,i£, ',-"Þ,'-, :~,~ --- -- -'--~~-=_.:"7j::~~:..~:'_:~'...'......l__...... - i ' . .--"'-"".---.."".. ',' .....'.'t-....--.....-...-,-- '---""----Î-"'-~~ , --:-- , ", - - GRADIENT " ~ ,';- .. ,:': ,,::' , , --1--1--- -- ".' ".'.::', " : " " , , - .' - ,- - -- COMMENTS: -_._.,;-~~,~..J'1Yl9t~:>.:"_..,.._,, "",- ,--. , ",'- , , R,pc'e.'.. ¡\'!II ß":'I~: ,~,~{i~lfD , 'Ft1Å~ 1 G .,~~9 ',ÞfV~$kON Of- <')11 A ' ,', .. AWt~JC,iiM$;4D ~Å$ ---_.._..!!~-, ~::. (';rg_~, (';.[=3:1 !! i."f'.l f1 WELL NAME ~,. T' !, ELEV. ., -' ~='--'IM11i:: !:'~ -8--l~r~ "gp.d' - ]..O":Q~ I l ZERO POINT 12' -.---:----,----.--.-., j,1 1!E.~23l.~ ' X 0 ~ 1 ..... ,.. ., 7 P. (t.) 7 It ' 'Y' 0 ('. 'J P. n V t'!. 0 ð Ii ~ , ZONE;¡ il": ~ è 1 t"J 1.~ 1'.,"1 r'. !"o1.I' ~ .....Iõ...' ""')".....1.." .~..,- 0;,. ,,",' .,~..\¡ ,,- r_1\; '- o¿ ~-;-~~-f"::"C,' C' ~P.?J;.¡-- ""'r.~~ o-+~ .Ht:T,.,~--;:¡Q!:;Ct u..:,. ""- .I.. tJ"..., ...~..r"':""'-'I--::'~.. ' I ',~ ."~~:~~~. . ' ¡;' '" J '..'.,.. - .."" , .', W IRE LINE SERVICE Kenai, ~Iallka 99611 283-7819 r E. G'~ MYERS { WIRE LINE SERVICE , \ P.o. Box 57 OWNER UU.J.O~: 011 c C . ~!!.!- r". UNER DJEICRIPI'ICINl..:- rer~"::.. ;;;;;;IL: - ~-;;"" at tB xo sle(',"le .9782," . -.- --- -,---- '-,--- -----, -- . , , _PURPO&E S1J1lic r.r~,H~if,nt su.rvF;~, - .-MARK~!3..4.ŒL.QIl~"'d~ m un i t " PICK UP.~MAXIMUM TEMPERATURa.:.... 1':7 f---~"-'~':-_~-- " ',' " , FRESSUR.:E ,- PG ,G, ' ' " , .3ØOO' '200 '4CÖ ,600 '800 4000 .~ 't. ,,'" ~:.m , SUBSURFACE PIESSIIE SURVEY :,1 ,... "" , ' ,:.. :... on (" -----,---- ,,'0' ' , , t I, ... .. , , , ' " ,1: , ,;. , 'I:..' , .. 't... ... . , '1"" 0' hc'" :-:"',""'~":.J - . ~.. i . :r. . ,; :, ;: " ':, ¡ ¡ .,. . , ;+;1' ,:~':~?~,~ , , ' ,', , " , \: " " ~ I, . , .. .. .. .., .. . t"¡'.. , . , .t: ,I . - , , , ' , . , - - , .. \..¡~ ',:':, , .~'ï'Ö,ÖO, ..,::,a' '::", ' , .. .fr.-I ' " , .- ,:~~~ 4:"::'000:: ",~i" t" " ,.~, ,,' , " " , , ':,.:¡. '.' " J;~:5.:~ 0'0.0 I ~,:t-t :; ~:, ' ",.... ::~',:', :" ~, ' " " r."I "',', ' 'I"'~ ' ' !;.'>'6'" :.","0 .. ",,\:i,:~ . ' , , ". ' ":"", <: , " ¿. . Ho. I '. :,\ '~' 1 ... ,1:9" ~ ,j: . , " ., ~ 01 . 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" ':", ' , '" , , " -: ' " " ..' , " :' " , ' , .. .. ' ~y" ' '\f';.oI...,....r~/;:'c.c: ""., " , \'""'._, -..."..ø¡..~............... '..~...... ..,- ,-..,,'- .-,..-.------ , , ',~~, " , " "'",, , .. " " ',,' "', ,;, '" " " ' ;' .'" ;"'" ; '~,~.,' ~,< " ,,' ,,',," , '" " , , , ' " , ' " .' , " , < , , ~- '.TABIUZATION PERIOD CIROS8 OIL RATE BID, , NET OIL RATE'BIb ' - ' FCIRMATION GAB MCF/D ,,' GOR CFTIBBL .CIRCULATID GAS MeF/D QL ..~ GRAVITY 8..;'1 " , ..M SID:' , ..: CASIfi!G II!RESSU"E " , " , ", . , , , ' , , - " " TU8ING PUS,SURE " . " , " , , , ' M. DEPTH' PRE8URE '.. aRAD.NT ". DEPTH - 1 r'\ ""I'. n . 1"\"] ,.. f ' , ' ,I . '., ) '.., -"" t') , 1, (\ t".l' ,.., 11 "l. r7 r-. ,~",v., ,',' , ~ Ct r:: 0 r~,,~';; 'r I ~'., '~.ÇL,.?('~ q276 , C', 0 r.. [) q 22.. f ~{,] ,", 1- , ,~~C- 9' 7(, , ( I ..., r: Q. ..9.l " (, '-J,i.~- .~:,') Q ""thO QO7f, -...=-t- ' . 0' ...."'(', ""'""7."' ...,':tJ ,(~,If' ,~s..co...-' (p r, .., , ,~~()o. 5 39~ ' "~.O ,196r"¡, '..:...l~DJ'," '270¡ ~T r~ n,' : U'~\ 1 ' .. .. " ,,' ,,'n' . (', ' , ~J of to .~7f}5 '. ~' ',\,7,,"r"',:~O(),' i . , y ..::.-. , 1726 '~i , :~.7l7, .: Oð,O' ..' '~7'lr: ' nSb ' , -- ~ . "":' ' . ~7U ,.,040 ' ')"?,,,'c OP;O':' \ 1 oJ', . , -: ., ,<"\ E;, , , n r?" " ' , I '.), .' . ,/ 1 Co ~f¡r:;'9 '.Ot? ' '),t:',~ ':.~o6tr: 3~1,:,4 ' .,O~"7, ' )..~ r)" 0 ' '060" .~ ,', ,I . ". ')""=7"" "'-77,' ',. ¡ ~, . \1 ',J.- ">: 1 7/j ~ 077' , ~CH:; ,1' ~ 1= 1 '" ., ..' .1: , I , ,', : '_Ön_J,:.o.~.:tO!!l: " '¡o: 10" 'P'. I!1~ . ' " , " r.. I~ ' ' ' ,-----"o_--~"" .. , , ... ------- , ._'_._-:~~' ~1+t~ -~-,-- 7-'" ~~ !I!!I.~~ MS":-, " " , . , , --:---,..._- ,.---" , ' " 11(' ..:,.<.",. ,.."""",I~"'\':;\.li.'l>""",\K,;-"":":..~".,!o":",,<'":,,~',,.:,., ",' '.., ",.. '..' ..0."" ..;"'~,.".' '. I,' , ' I I < ..' -" ~'. ,. , "."" ':"'., I ( .', WIRE LINE SERVICE ,.~ E. G. MYERS WIRE LINE SERVICE ( , ! P.o. Box 57 Kenai, Alaska 283-7819 SUBSURFACE SURVEY 99611 ::1: u~¿~~- ~~.~~~_:~-==-=~ -----~_.._==.--~-~=---.-~~-~~ =nK~~~~=_~--~~~-~t~ lQ.~~~~~~.... --~~~~. N:~;8;6~_..~~ LINER DESCRIPTIO~- Perfs_!-.-.2.884~-__).OO9~_____-----_._------------_. -------- ~E:.~.9 POINT ---1?._~..- ~!,_TH_---__. _.29.19..'____. -:;;1~~E-;"~~-3f~-ot:f~--~-o~~~~Ü'~Y~~Ði~'-..L. ~ç_~ê_l~~i~-944-8-~~~---~~~~Q-' ;.~-~ ~ON~ _l1j,dd l~.Ke na i D Zone 9782..~_otis Q ni PPJ:_~__2.BZí'j end_Q.[_tu1!ing_9.ß.ie-'_~.--_-- ------.---.- - ------------- -_.._-------------------~----------,........._...----_.._. --.. --..----.------.-.. --------- - -------.-. '--------'----""---'---" ..-..--_.. ,". ' .. PURPOSE Static grad ient- su!yel_..___------,---------------.----....------ -..----.-- ---'--------- REMARKS .--.----.-.-----,--- .-'_...,-.....---..., -""........- --," -.....,------- ELEMENT 420o --~ s~-; N~,~4Qz==~_=='::.~~~~;J_~~~~'~-'-~:-.~~~~~t~z._:::~!_~~~~-_.--.-:- :...'-~==:~-=--=:='~-~::==---"-- ENGAGE STYLUS -2..L4-..5-.1h.~~._-_.__~.ISENG~E STy_~~__12: 01....§.--!.Ln--L_5_:-:2-h.2._. --- .----------..------.-- oes. TaG, PR_~~~~---,--1Q5Qt_--_-..:...._._.- - OBS. csG.:_~~~~:.._.,._--_.--_.,_._- _m_- .-----.-.... -----_.,_.---------- COR. TBG. PRESS. _...--3.063#-____---- . COR. CSG, PRESS." -----~---'----'-"---"ë¿;:O-'-'-'-'-----" ..-..-.----------.---. PICKUP (¡>~ - 10,01)0' ,TIME ON BOTTOM 10110 p. m.!.__- MAx,_O!:___.J2.1_____-------- '-"""----------'-'-"------- WELL STATUS -- S.t.a t tc;---~----_.._. .--...-------.-----.-------..---- ----'.. --.- ------ ,.- -- --'-' ST AB I LI.~~~I~~ --~.~_'?.~-- .---" SHUT IN -2:)0 a. m_!.___------- ON~~.:.'.O~-------,----_.._-- -'-"..-...,,-.-.-.--...--..-- ~~.~S~::_~~.~:_._~¿':..__._--_...------_..-- NE,!:..O}L. ~.:' TE_E!L~_.- ------..-- 1~ ~~.':'1~ ~I.~~ <3~S ~~j~.._--_._--- -- - -- -_-:--=ro===---= =: ---'=-==:.=---='-:'='=:-'---='-===.'.c TIME DE PTH ~_DEFL. E-T GRAD. 6/°.. TIME -- :EPTH, DEFL. P-- .. -- .. .. -- --- -- " '" ... --.. .------ 1 .. ~3::~ f ..~ I ----- -- ------- - ----...-- --- -- ~- -- ------.. ------ _.._,-- -.-... ., -- - ._- .--- ._-.. .. 1 ~,'~'=- .--.- --.-- 1--. -_. ~- -- --. - -- -- ------ ..... ---"..- --.. --...- J --- --- - -. -- ¡-------,- '-"'-.. -- ---- .-.-- -- '-"'-' ---- i----- - .. ..-. -- -- --.- -'-- ., ---- -- -- --,-----. -,--,-- '-- -"- ---- ---- --~r - -.-, -------"-"- -- ..- ----- ~.. -=-~~"=;;_"":C~-~:~,': -- --=~-===-=--=-==- -::.-::..-::..-::: --- --...--- ~..!.~-~~!~~ GAS MCF/D OIL DRY GRAVITY °API -----..---,,- ..-------.--.------------ BEAN SIZE -- ----.--..-- CASING PRESSURE , 'I --~~~=~ .~t~-=-.. ;;~I~~~~~~~------'--- -"--'-'-'-'-'-------' ---I _.._-----~..------ l.ÇhÇ)J)Q ..9J.2Q_+J141 QO ---_.~---., .---+---- 9.,..9 C, () , 26 '126 :t.14it.@ _.._~,._..:_-----+--,-----._-- 0 '9Õ..ü-- ()";,~ J21 -, 040 .1 I .;J+ -'- -;I.I.....(.. - - - ...I..è_.. --t'-----'-1"----1 9.~~5Q__. .2Zz6. .-3115- . OBO- ..- i-"'-'----.-i"--7"~"-i 2800 - 9_17_6.-31.Jl- --LO40 -- _._n_'-¡___----i 225D.._- -9J2.6- ..J1QQ 80 --1'--------1"'----- '9..oD.Q.----flli1--- _--Jf155tfj. 067- -'--1---'--1---- D, c:np.__- ..68..21---[ _J.5~ ~ --l-.--'.,' "-1-"'----'-- 6,_Q,O,',D,.__.....;.53SL" -:>_--t,~, ,",-~.2l7.., - --l2Þ7 ----r-""-'--¡---"-"-l4£:()() '10hC: : JJr.q 062 ~f:~=l-~=~j ~:O~r~f:O2~t=+"in',r., .~j~~i~ - :t~= t:~:; -J ~-~..-: ~~ ~= :::l=~~-f.~-- , ,', , COMMENTS: 1}"~,,,!" ~~~,~,""'~,',:,:~ I "'1l ,~4~ 'I' \, h,~,ItI\;~ !~'~ I) Iw ~~. ." t , '" BY:__,--_...,_.. Myers ,.. ..,'" "MAV l' i~ 7gr'q ; "n - ""')~ <., '.. l. . ~~J\,b~'bJ"'1!-. ~. 1 ~\~~"~I"~ ~I)r' .<", ',' JH; ~""~J [ Ai~~ "¡'~~ .,.".",.pr¡d"~'1""~""""""" ~~'i,..r .. ~;'\'l~',~\>\\. ," ¡ "" ' t " J -, .. ( yo' '~ E. G. MYERS ( WIRE LINE SERVICE , P.O,. Box 57 Kenai, Alaaka 99611 283-7819 SUBSURFACE PRESSURE SUIVEY OWNER T.! l' Torr rT Cl~L . . I ~G '"111 . UNlIt 'DE8CRII!'TION: P t'" r""" ~ aPP , . '. ~ WELL NAME Y: T1 !j IM.TE: ~-e-69 ] ." I .'- 1.1 ", 'c:. FELD 1,', ¡' Y:Æ= i '1.::: ::~ }i'1. f:> : d EL£V. 1 r.r)~ 'H . ..' .. f '" ZERO POINT .-.x~ ------- '),i"" at.;.... I " , . .., ;;0 ~ lJ . q ,'., f.c ,., , ' ,;:.ep~e 'f...t."... roBINS DETAIL: , XC slf':~Y(! 937 l: I. X2... elp.f\"lfl. =-:'4 ~~_~I, at 1. a ~ rlj, unI. E.' 9 8 ~~5 '.~r..d 0 f t't;. b i!'.~,,: ~ ,,\ ~ £:~ f"\ , DEPTH ,.. .' t \ J ...:...!..- 1'.'1' ; ñ ('3' c. J." Cat) "", ,~ ZONE:.':'-\ ...;.. .... ~",\- q~~I~~. T', I,J (' :>1"\ f' , t' -- ,~ , ',', , " . ,,' ....:.:'; , , , , ' ,,',.,.. :' , " ". , " '.. "",' , ,', " , , " " 8VI:- r~t :l P. rs'" . i ~'~~ ' ," " " , .~...._.- ---:.--:---- --- . ' . " " .' " " , . " , ' "', ",' ' " , " ' " ,.' , " " " ,,',,1,:,' IM\A' ~,':("'~ ~,'",'.\¡ :.~ 'f' ;~/ ~,'~"', ,'. , . n 1,$:. ",', i;: t' - . '. ¡'.' WIRE LINE . . SERVICE ( W'IRE UNESERVIC{ P.o. Box ~7 Kenai, Alaska 99611 283-7819 SUBSURFACE SURVEY OWNER UNION OIL CO. --------------- ..-~!~_L.LJ- r;.l!_t~t_g~:'3__--~)eJ~p.~_-_wE~~~~~~_J~..J2- U _12:__-_-- CASING 7" , ----- ----------~LE._~' - - -, .." ...- - --- .--- --. .._--~____YAT~__5~6-69____- LINER DESCRIPTION Perfs. 9884' - lQQ2£_____.._--_... -..-- ----- -- - - -- ----___-_n-- ZERO POI~__J~~-_._-------- ---------..-.-....- ..... -- --- --- -----.--.-p -..- DEPTH 9..2J.9_~_._-- Otis x<?- sleeve ..2.J~-~xQ....-~+~_ê~2..~~8~.-x.o_....?1~~ve zONEJ1i~kD.e__Køna:LD Zon~____- rlipDle 9825'. end of tub~.!lr: .~1ß58'. --------------- --------------- TUBING DETAIL }}It I 9782~- otis. Q ----_....- ----------- ----- ---,-------------- ';"':.\'., "':" PURPOSE,' Stat]." C Bu]."ldUln"" - "': ,",' -, ,-;.. c' - '~;'-' '--'7;~:::-:-::-';-:-:---'-.::----':--.;--"-:---'--"--' ---..--..-. ~:.._---~-~---- -~~._~--~~;'-----~~---_.~-~---- :.._-- --~-~-~--- ---------- " , I.' . . REMARKS -_._- ..-------"-""'- -_.- --.--, ELEMENT 42001 SERIAL NO. 340¿-~-------~~;-h(f-------:-l:r--;~R-~-'------------..----------------- ENGAGE STYUJS ? Z 30 a. m. -----~---,_~~~~E STY~~~2~;J3L~_. ;-~--_Š~~~~Ø.-~-'= =-=--==--~~-~~':'.~-~~~.._..- oes. TaG. PRESS. COR. 'TBG~ PRESS. 2725# O8S. CSG. PRESS. . -.----.----------- ---- ---.-------..-.--.....-.--.-- -----..-.- ----------------- -......._--___m COR. CSG. PRESS. 8:)0 ~-' m.!-~:~~==-M;~.~-F j4q~~=_= --..----.....--..----.--------..-- WELL. STATUS Flowing- Sl}ut t11.' .;!!:!.~~: )0 a. m. PICKUP ~! TIME ON BOTTOM --------_... ......,----- ,-----.-..------- STABIL.IZATION PERIOD ..---.------.----.- --- ----'- ---.----..-------- ---.-------- ..---....--- -....-.---,-..-..------'---- ON PRODUC110N GRoSS OIL. RATE BID ----- "-----'----------'---'---'------ ---------,._' -- -.....-..-.- ...----..---.--- ..- --. . : ., C;8 hr. Build 11 " I " NET_~.~! TE _B!.~....__- --.:-.---...-----.-.--.-----.--- F~!:1~ TI~~-~~~~~~t.D.. -____J~I ,~- 422._____- ~~~_~BL_,-- ..__'____n_'_":"'___._--~. CIRCULATED GAS MCF/D -------..- ._--.. ..----,..-1---...-------- ---- OIL DRY GRAVITY GAPI ------..,..--....- --..,..-,-------'--....- i TIME --------~_.- - DEFL. P -;- GOAD. ,,-¡;;- TIME !><P!~ D;'~:~-:;-~~Fï:;= - '. --- -~=~ =-t- =i:-r~" ~~:::':E~~~~-- --- -~ .~--~~. "" -1= -- ' ~ TU!'J-"GPR§?~~~:=~=-" --- ---~ ~ -r=:T=~-, T~-r- '." . M'" ~E ;;~~~-~ ~~~t;,~9URE -GRAD'::- , "',.. ,." -¡-;.. r-, --+-....-¡-... --_.. ,- -- f-I JY-- -~+:=~-,~=~=-~, ' -- -= -:: ."---~;;,',~~.#-"~::-t~ . --=--:: .. ..t .. .~.~ . ~I ... II--:=j --T:::~~:~:i:::;- .~-=--= ~ -t~--+---- ~-- .. - . -hj. ~i-~~-~=F -- --- .~ . . =-J ~ --+-'-'-""'---+-~--' , ,- -.---- . I . '. ". . '- -=--- - -- ~- --,-"---'-'-. --=-¡----:-j--:"""l ~,--, f'~ -. ~-,= ------ --~-. - --=- -=~~~~ ~~(:~: -==-=f=-3 ~- -~~~ =:~:L:-=:t-~ -:~ . COMMENTS: Off botton: 7: 30 p.n;; 5-.e-~9 --- ---- --- ,-- . . MAY 16 'f)í'lJ .' ,fl'Vt;\¡4~~N: ~~f OI~..A.~~!) It'~~ . By:_----_____J1J~~r~.. "....._-,-_._-_.._~;,.__....~-_._-_.~_._._..~~~~~!.:~~~t$t: ',' ~ , ' ~ WIRE LINE SERVICE ~808 Box 57 Kenai, Ala.ka 99611 283-7819 " $ t ,E.'G~ MYE~.S' t'; WIRE LINE SERVICE " OWNER ~~; ION r- TT "'0 \..: .,o..! ',; . -' FIELD r: f' !H~ i (, ",$','.. ~,:: I T"I,'¡ n 1 r~ . -, ".... I. ". ... ------ - --,--_..-------- CASING ...", I , , ELEV, ---- ~ ~-LP',ON: :.P. e.ciS.-.....9.8fA..~- : q 1~.2_,_, , , ~.ING 1IET~~_Q.:tj: S' X Osf€~ ':.:¡"- :;¡ -3 71~~j:t)-~-F'~ ,. P ~-B.i£.e.n, q 7 32'. got .i Ð '1. n i 1= 'P llf'~L~_~..; ~.L_!: n è 0 f -._-,----,- ------ -- ---- --- .' .!-URFC8 -,~ t E'..ì.i c Fi~ ~ -,.- -~: ' 1'.., l"'møY1:t.:: ~!'3,402 '01'\ t.a,n,d t?:~L un:i,t.:- PICK UP ...:...- .~- MAXIMUM TEMPERA"'E ~.- 8F II --'._-- , ' , ' ,-HOURS SECT IN 20 40 ~ .,. WELL NAME r~ SUBSURFACE PRESSUIE SURIEf "', IT ...' '- 1" ., ; .::. ---- -:"'\ ;J 7. 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'r+t"i: ',rc,P J.,n; :t1'f:~' ~r;l " "!':;: t: ~ " r.t~J.. ,1-~ ,: t' , 't,.,t'I:i1-:¡.:r"""'~'1.",:,..,¡...,....~,r'fI'f.1,.w."'H",."..J",""'+1".""""';'" -.to '-H r' . ~1" ; -'~:L"~' "~'t:l't:~~ j1fi ,hi-:r, TI9, {¡~1\J:f ~H7",lrt.H :;:HtHtl,f, ,ttr.;, 'fj.Tl .l.t'~'t Jftl' ¡j~~ " 1"+ .. j,ttt'l r ".,.. 1,.+ ..1-+...1"'" ~:'¡¡L":",,.,.~i......-....t,...¡.~ J,;.~¡:ft'-H' ,+. ,,1.i1........, ~ ~!~ fo '~'~! "!.t 't"l' .I'r!'- .t' i.HI':tt~:l~;Et. f':r"' "+.7 '1"1 :'~1i'~"1"!' ~t't:.:: ~+'~ .¡,I.... t1 1::t.Í"J ' ;,. J',." :;1- ',~~, ~l*d~, ',TJ..tiirihrœ1~;-E ~~t;. ,j~ ,ift.f:fUf ~tt t1~4, F..:rl.!:1f~ ,~,F; 'I~' :H'i:t i :tì': ri1:4' ~'¡,:i". H:a ~:tD: i~¡t. J;1J:l '(f.~YtÐ:,t' '!~,:, r ':r~t~ :;rft 'un '~i;'j {Hi, ,t-;tt ~ ~fti ~t ~1i' Ii,t ~r.T- ~~:¡:t 'fir; '~~ t¡ ~,..~.. )t:J:I.:~:tit L.,t.;' ~;!t;:J, ..1':.3' :t,t~:~ r'¡.~:,i, -tlT~, tì.,.¡.' .¡~' :rIll ;fl 'J, ,r~ 4~ ~+ I,TI t+::i: to.. '1+,' .' ,+, .J. ,,- :t . + . .. ,, .. I 1- T' :n;, ¿,,~ -t:..o :.;. . . ... ~ t ¡. ," , . , ., , .. ~ " , ',.. ,',,: ' " , ~ ',;,,>:,,:, i. i:. ^" ","', J-"\/"" \;\ I " " 0' : ' :.. : .. ;,' ",.. :' : : .." ': ",,' , " ' , " ,', , , : '," , , " " " -- - STABILIZATION PERIOD , , ' '" GROSS OIL RATE BID , .NET OIL RAn: BID ,- , , FORMATION GAs MCF(D 'Gal CFT 1881. CIRCULATED GAS McF/D , ' OIL DRY ,..AVITY' °API,' ' , BEAN SIZE, ' CA81NØ MaSURE , , " TU8.lNCI PRUSURE: ~, , , , ' , ' ,-.. .,.._~_æì.ME...~."'V, ' " ~,-,r,J::¥r».H. IIRE--. '~~NT " , to +. 'n' "- '1 ',.~: ' '1 ' ,_~,i~ __,2 .... j 11 " 3r:,u: ~h'3q 3.ñ4 6 " , : ~ ,.. I') , ',oC)...:." " ~l[ur. . .. , 3ñ~::', '~667 1r."'" ':" ...' , ,~, lQßj. ~ 6.9,0 ~ 6<1!1 , \),703 ~ 7f1? J7l!- ~ffi 1 .L.' r .. ' .. , .¡" - , , , , , ----.---:-,. t; , . --,. ..-.lC: ' : J.d', " 'p ,--_J.. ~, -2A '" (') , . 1'; , " , ---..-.11.2.. ~~ (', -~-~,é"---, -_.....:.;- -- , , " ~ ~7 ....,. .' , t:'. ~. , --- --.u,. -..- '- -,.,-- .---.-.,--- O.P.'Ç' . ...+ ..., ! -~ ('\- n ' ~~--.Q.Y..IL:t om: ' I ~!.m. , ------~ ' :' --_..._,._.~,--- - -,'~=-~'~,}1ÄY :.1.6.- i~g , -:=-~.:__..~ ' , ' --1WISIOR-ö; OIL ANo GAl ': ;,:8Ÿ1 ......__.~.i1y'e):ßÓ1~~.,_..".. -." " ' ,ANcHOMGE '" ',"'. "----_."---""-,--,---_._,--,.__'...__n__- , , , ' , , ' "" , "', ,'. \' '.. " . "," j, ,'" , ,: I, " ,", :', , , .. ' WIRE LINE SERVICE ì' " . WIRE, LINE, SERVICF P.o. Box 57' '.. Kenai, Ala8ka 9(,,11 283-78]9 SUBSURFACE SURVEY OWNER UNION OIL co. --.---... --..- .... FIEl'!) Kef':'" i. .9::'f?.f.1_?J-.d. -----___~~!:-L...N_^~~_..::1{ ))_.1:.._12______.- CASING ~-------_._---- .----' -_._._-_...--_...E~y'.--- . --... -- _. -_--__.._E~::r~..- ... S-/:~.-:f):_- "'--"---------- LINER DESCRIPTION Perfs. 9884 '_:::JOC~2? ' --- --...-------- --- - .-.- .. -------- --- ZER~~~~.!.- .J..!'2.-'_._.._----------_...._---- --.. DEPTH 991( . --------""- -.... .----- ...... --- .-""-' ---.. ---- TUBING DE~}f'-.-~--0ti~-;;-~--s~Y.~3-:37~-~~~~_~~~i_:-l~~_'~~- -(~~~J~.F~_i- t- :¿'9~§_i~~e~(-", ZONE !-1idd 1e___K_~""Il~~t -;¿_3-']r1F'--- ,----- -2.7B~.'. otis Q nipple 9R.?5_~__t._f)nd -~r..J:~~J!:I~:_~'~5..A.'_.... ..-- -.-. ..-- ,-----..----. ---,,--..-----------'.---- ----------------.-.---------.--,'.' .... ....,_.... .. ..-..'. . ---.....--..-------..--- --..,,--. ----.--------- -.. -------------- -.---------. ----._____h_____... - - - . - - .-., ...----_____n_--_----'" ._--- -----------..---- PURPOSE Static Build up' " . --_._.._-_._.:-...._-_.....,----_._.._._.--_._...~- .-.-.. . --....-'...--..' ----""."""'-------'----'--.'-"------------- REMARKS -----------.-..------------. - .----..-....- -- - - .... -- ........-----------.----- ----.--- ------------..-.---- i. ---------- -----------..------ -. --------- ..----.-. . --.. .- ....._.. -.-..- ~~T 42001 SERIAL ~~_..J~_9..2_---,___~~~K_6.9_____. .: ___..__1~1~-_!~;;~---- ----=~-=~:=.~.~n~~-~-_._~:'-~-~-=~~-==--~-==-'- ENGAG_E~~~_2.û.O a.m. -~---------~~:>~-~~':.~2:.Y_:u.~-_.. 9.1.3.9_. p_._!!¡L..5..-_<:-6S~- ------------.-- --_._n_..___.-_.___Uh_...._n--- OBS. TBG. PRESS. OBS. CSG. PRESS. . ~T-;.-~-~~~-- JJ..25i1__~__----.-._---- ..... '_c_~-~-;~~~-~-~'~~~-"-"'---'--"_." ,-.----------- .... PK:KU P @! .~~;E~_;~~;~~.ec.;jQ__~:~~~~~..~~-'_:~_.=_:_=~-~x:_-~-F.'---~l~!-' O-~--. .-- WELL ~TA~US Flowing- Shu:.:Lj.J1...---------------------..-....-.-.--- ----. - '.-"-"--------- ~~~_._..2.!.J.O a. m. ON PRODUCTION ---.---------.---------.-----.--- -".---."..--------. ..,-,--.-------.... - -.------...-----..... .......--...-.."'-- -.--....._---___.n_- ---. ..... !" ---."--."""--"-.""'-"""""-.' ,-,'.""_'n_._...._----....--..--.'- .-....".'-----'-.....---. _.._n..' """-.--""'--"-----".-- ...--"..---_.. STABILIZATION PERIOD ---'--___"__n.._- -.-...... -..__....n""___.'-..--.._-.-n..""-" GROSS OIL RATE BID - ----".-'---.---'-- .... -- .-----"-'---.-..-- ..--.----...---- .'.. , ~~-~...~~_'::_~-~!~ .~lD.- ..- ......_".. ---'-'--".---"'-..--- , -28 hr. Bu i1d 11 P ", , ' " . ~ORMA_!!9.N._~~~-~~~(~.- -_l.Ô..J{~~;..---,,_.._------- TIME ~ DE P1"H" ..,;;:--- P- ;:-'-;;-;;";;;"I~ ~-C=-l='¡=-=-T~-~=~f'--=="f"=O='_.- '1 GOO CFT /OOL _PI W],]1 - . -~CL- "~{~H- ~EF",.+,::::!... -"'.^.".o.-c'!!'.--.: ~~~~;.';F:;;'-~==::=-~-==---::~~ ".~: ~r",q:í6 .J 66- :, ---t-~=-=",=: ~,-~~,-_J,,-=--,:~,-:,l, -~=1,:~=,,=t=~,:-,_.=-,~~,:,' ~,~,,~~-~~U,-~,-"-,.,--,=-==-,==-- ~~= --, +-,- -- J....:!. -j,-----,""------ "-'--,--- '---"..._{.._- ..",', +-,~'---j_....,----=l,- ",---,--,",-, .,-,,-, -1 M. DEPTH V. D, E",P.T"H" .1 PR,ES,9U,~, GRADIENT, ~i .J-~,: , ~6 -, . "1-'-"'-----.___,,_1 --.----..- --,---'~,," -'-_._---+--~"---I,---.-l. -------;".-1, ',=~.~,,_.~ ~._~--~.~..¡:.~~--_~=___I_== r 4 1" "" "~6~ --t--,-~~~ - -----~_.,.._-t-----:j-----r--._.. --1_----- -"."." ."..".t--- -.-.. --------- .~~=t ..~ ~~~R~-, .,.,',- -"..'".,-~ -"".,===F,--,',"'.,.:,',-",,-,:~",-=:¡t-, ---"',+-,,-.,- -,.,1-,', -.,.,1: .,-"_.,._",-;"..==~:.-.:_.-_.,.,,.~,-~""',---~-,-,-,"--,"",,'~,,, ~--:,;",-- "l~_~J.~ .,," ,,' 68" .",---"~~. 2i'T.~,~~-,~-~:~-' ~."?:-:1t-"--J---~=j --c~ "'" . -,:-~.,..'__..,~-,::- ------- 1,.J___- -- ~6 , --- 'f.' , ,--,,--, '-, , -, .:t', "_.',-. '4,---."';"':'---1,' _._,""-,-- " ,'--,-,-'--,,',-,'-- '-,-,"-,1,---"-,"""'-----+1-.------"'-, 24 II ' f¿2 ¡ =+ ' I ¡ ----+...----- -. -., ;---,-_.:..~_._------- .. 0 ,--- ---- ---.-..--- -"- "-_.---"-ì----'--"_.--4 I I I " _!~-- -- -1'Z! -," ".--.--....:, ,--_.'-,."~-,--'_."._-', , ,-~~-c.t-,-, -' --"--jt--_.~ =~~-,1f":'-':~:~-'_.~...' -".,r,:~~=~, -~:-~=~~~.:~ " .J2Ö -- -- --- -=----r-=t ---- ----~ ~-- - ---+---- --- -~-- i" ~- - " ---- - -: ,~.~ -i=~ -1~-~ --c~~ - ;~_:.--:_=¡::-=- -=--= :----, ~-~ -" -"C"C ---=- --=-~~ .:.= ~-=~-~--=- ,,~::~1 =:.~l=:--:1=--:- :-f---===- ~- ~L~~ - -~~ -- - - ..=:~-1;~~ ~--:;£~~j:=-E~ ~j --~~=-=r-- ¡~--~:-=C-~-~~-~~ "COMMENTS: Off ho'ttor¡ 7:30 p.rtloJ .5-8-(,9 . [t\)"'r:".~,,. ~ " ,nf~r~~' Ði m~~' ¡e tì9(fg BY: -..--. ~1.y'"q.:r F.; " ,~V~~:~; ¿~~ ~)¡t on. ,A~ ~ .."."."".----'----'-..-.-.--------.-"-...-".-,, .."---'- . ..'\'o":""""'~~~~r: ~ """"" , / " ,= t ,"', ':' ":,wn~E ,<."-:.,t'l NE r__.~SER\lICE , '>',' ".,' "", ",'" .' , ' J' ,E. G. MYERS, ( WlRE LINE SERVICE ", " " i i ~. r P.o. Box. 57 Kenai, AI..k. 99611 283-7819 SUBSIRFACE PIESSURE SUIYEY OWNER m!.IOIi...:QIJ: 7~' co. FIELD Y. enfl:L_Ha G :r~ c.:~ WELL NAME v ,., . T'" ,I .'l~ " DATE: , -F.. -(.9 l.2.! DEPI'H 9216 . ZONE t1 i d d 1 fS - t.~ t":,., 1='1. ; p,~~'- CASING ELEV. !::'!!!!.R DDCRIPI'ION: ' ~f':. 9ID" tQ.Q9 2 ' -., ZERO POINT ;;;.; 18TA!!::, l~, ", Qj~ i ~ x-o...ß .eeve (JIB 2' , '!1 7n~0 , , " ---' -- , ,; : ,: , ,,:, ,..' ': ," " "'~ " ',' .: '" ' :, ' .", :",-: ,> " " " " , , ':' " '... .. ", , ' ,IM8IOM Of 'oiL AMO CMI :.-_;:,+~ .a-'HOIfGl ' ' ", " ~. , .. ....j ~ '~r" /' FP" " ' , ',,1~lyer.~~o1Ñ~__':':- , , '. , ,', " ',' -: " , , ; i, ,,:' ,...' :' ' , , ' '.. ", , , .. , ¡,' " --- " ',' ':;',' " , , ':, '. :":; " , , ," , . , , ," , ',' " " " ',',', ".. , ,', , """, , .' " ': ' W" (' L ' \...) ~ - 7 /18/7'~ 7/19/74 7/20/74 7/21/74 7/22/74 7/23/74 7/24/74 7/25/74 7/26/74 tit 7/27/74 7/2g/74 KT~"';\I I)' ,(' 1,"" , , 10,522'TlJ 10,477'[11 10,52Z'TD 10,477'[ ¡ \',LLL I -LLU¡ lJ ,...1. T \.l.LL I:u. Jill!! (-- F ILUj Kenai r:1S Fie It! TrOI!S ¿: RE~~LTS (Footage 0') Dull1:caclcd ¿'-oTl. tbg. string \4 65#/ cu. ft. 1,,'0 f111ill. Insta11eG rr\~. Degan Turnkey rig ~ove G 6:01 am, 7/18/74. . (Footaf,e 0') Completed turnkey rig-up operations 0 6:00 pJ:1, 7/19/74. CoITDenced operations G 6:01 pr.l, 7/19/74. Dr1g. rathn1e. (Foot;J.f;C 0') Circ. 65# fluid d'\n. thp,. 6 out annulus (thf.. plu,(1~Tcd \':/ sa be 1m,; top hyJ. pkr). Installed BPV. Rcnoved x-mas tree. Installc~l ~ tested EOPE to UOCO specs. (Footage 0') PU on 3 1/2" tbg. & released single hyd. pkr. @ ~û1S' [¡ 940 lhlablc to Pooh clue to s\\'abbing. 1;"orked t11g. Circ. ~ condo Mud. t:nahle stop s",,'ahbing fron htI:l. pkr. RU Go- International. RI1! to top of sand G 9745'. Cut, 3 1/2" tbg.J 9730'. 1'.'orkcd tbg.-tbr,. not cut. fUr \'.1, tmit & closed "XO" sleeves above + be1m..; top pkr. Circ. thru cut shot Q 9730' while "'"orldng tbg. 1':el1 still s'\ëlbbing. lO,522'TD ' (Footage 0') Unable to part tog. in Cl1t2 9730'. Recut 3 1/2" t1':. l1 9,735'[1 9735' (~Pooh. Laid ch\n. 3 1/2" tb,:r.. 4 accessories. Left 119' of thJ~. & fish in hole. PU OS 4 jars. Tnt. Pickingup 3 1/2" DP. 10,522'TD 9,782'1:11 10,S22'TD 9.449 ' ETr 10,522'TD 10,461 'En (footage 0') TIE \.:/ overshot pid::ing up 3 1/2" Dr. Fonnel top of fish @ 9782'. ì'Íorked over fish-wlab1e to hold onto fish. Pooh to chccJ.: rrnpp1e. (Footage 0') Pooh. Ad(~cd extension to overshot. TIP. Latched onto top fish @ 9782'. Pulled 5 stds. Pkr. swabbing lOO~. l!nablc to pur:p hy p'1::r. on armulus ,\/ 3000 psi. Rir,r,ed up Nt unit. Checked top of semel in fish 10' belO\~' overshot. Ran bailer-tmab1e ¡'o hail sand. ' (Footage a') Pooh. Rec. ply. & tbg. tail. Tagged fill G 9990'. CO to 10,461'. . RII { w/ 6" hit & 7" csg. scr:lr 10,522'T1, (Footåge 0') Circ. Ô condo hole to lop. Pooh. ~igged up f'to-Int. ~ 10,461 '1:'1') logged Dual ;~eutron Log iron 10,300' to 9000'. Pan CBL-VD Lo?,- fror~ 10,300' to gOOD'. Perf. for ~':SO test frop~ 10,006' to 10,007'. P~n 7" RTTS tool ~ Imp on 3 1/2" 1)P. Set RBI' G 10,069'. Tested to 2000 psi-ok. Set RITS tool G 10,020'. ,Tested pcrfs fron 10,023' to 10,03()' for comrmmications above 4 bc"lOì~' ,.J 1500 psi -positive press. Held 01::. 10,522 '11) 10,461 '1:T1 lO,522'TD 10,46l'L11 > s.-I-~:\ 7" cJ, '/~'l(,.T'rVt:5ç ,(r (..5 ~t1H- 4-~'\S eS'( , . '~ð '-' , . í'/29/ì~ .:- '\ ' ..., ..., ~ <: I I'" t". ï,;;;t r"', F ( ~~ 1:-~) 1)5 ð S.t.., :;).Ofc.7f51 (..1 ù ...., (J. c.~:"e-r' Yòc \.. (,::' / D I i :F ~F. "( - --' .I.,. ':: H '"~ z ¡ ¡ q- t) S I 3<;' 8 vS ì 5 7.3' f5 ì L!, 'i- t) I) Sf 10,522'1']) 10,4611rTJ ""\ ~ "') )..1 ~~ 1'.t~. t (Footar;c 0') I~cset rrITS tool @ 9990' ~ tested perfs fro:\ 1°»006' to lO,OOï' for co;'nmications ,.:/ 1500 positive psi-oJ:. PicJ"cd up PFP PI T'oq1¡. Ran D<1ker cr:t. rct. on 1'.1~ Q set \\"'tr. cushion. !"'ositioncd tool n ~ì:)5()' f¡ fluid U-tllhcd prior to setting tool. Pooh [¡ fOtmd PI' ,.:ashout 0 ÔS39'. Cor:lpleted Pooh. Checked tool ~ replaced clocks ~ press. bomhs. (Footage 0') rJI [ \\/ ])51' !! 1. \'.'1 2000 psi wtr. cushion. Set pkr. ~ ~!95(ì' to nry test perfs. ,~ lO,nO(j' to 10,007'. Opened tool 0 6:00 [Un for 1. }'L Tes ted 1)rv-no fluid entrv. Pooh G lay Ùh11. test tool. Illll - 4442 psi IFP - 2037 psi, JTP -' 2037 psi ancl FI~! - 4442 psi. Picked up ¡;Ùl1 II pk1". picker. nTH (¡ milled over Baker a'\t. ret. J 10,018' Pooh [{ laid th\ll. tools. Ree. all of rete (Footage 0') Co¡¡pletcd no cmt. ret. Q 10,018'. Pooh \-:1 rete '~¡j ro-Int. J~aH gll:l::C rin.': :~ junk L;1sket to rTD :] lO.,H)}'. Perf. 4 hpf fTor" ~,ì~)l~)' to 9920'. Set O:lt. :rct. (? ~)DSO""l:l. PJ1 r.o-Int. TIP ,.:/ 7" nST tool.-Lnc;r' on ret. Q ~)~)SO' (j set tool n ~)915'. Ûì)cl\cd tool ,,;j l~;DO nsi ,,;tr. cuslìÌoJl Q 9:.1 5 ~:1: for 1. ] 1 r. ,.Lç) -p t.:l~2,1.D.:.lri:l.L.l2f',-~f ~_LnJL:.L~:i~~~1~~~.~.tQ.:.5!,~2~'),' . J)ecct ¡'(' t"",'1. ."""11 ) (I'" il)/ "1""\'" '1""("\1 )"'1'¡'-' r~'n'" I,'," I t'l"\ n(I],)' ()"("H" , ,,' - _.."L,)).,-.l.,...".,.....","........~., ""_""'"""""~"""'~'-""¡""""'¿""'-""¡"'¡'"."'~""'~'_....~~':.J....",~I..u._-,.""',,I,i"'4.___""""-"'-"""'""-'" ,...., i', ...1 t".-C)-O--";) ] ).."; "l',I~J".1(,l C""t'ï)'\\" 1,",(1" Tl\"'l'j"c" 1"'1':(" "'tr 1(: '1",("'1';"(' t']'!' \ ',,'J ' cIi"ìd , ", ,'. 0 t J" " " " 1 " ' ., \ . . ,'" , " I ,"'," . ,. , I,', l . ¡ '.,' ", . :.' 2:30 PI:!. C:lo~;cd ill tool.' :):()() p:;\. P(1oÌl ,,'/ ¡;:rl'~; Ii fO\lJl<1\;tr. Ic.vel: 272'. Jbll 40 bbls h'tr. entry. liad Sf of sand fill inside tool. W\SL 7/30/74 7/31/74 8/1/74 8/2/74 - 8/3/74 8/4/74 KE\.\I 1ìIT!( ,,' ~ 10 '""')? 'T') ,~..- 1 10,19~'['rn 10,522'TD 10,198'ET1. 10,522'TD 10,436'[ 10~S22'ID 10 436'ET , \.T..LL I.u. --ill( -TAl S GF CPE~' - FILU} I;(-n~i ra5 fic1L1 ,\: RESUL. TS (Footage 0') EO rete g 9950' ~ pushccl Ò\11. holc to 10,19S'. ~ct isC'latio: rct. 'J ~S79' bet\,'cen D-3 Zonc proJ. perfs froM 9SS'¡' to 99l0!,f¡ olcl.Dsr perfs frem 9S5.P to 987'+'. Rnn ï" RITS tool. Displaced f'r \J ~:~O psi r:a: press. Set RTIS tool G 9822' ~ blced off gas press. Unloaded \,1:r. in Dr -& wcll produced dry gas @ a lm,- rate. . (Foot3gc 0') Completed DST testing perfs frop' 9~1S4' to 9374'. ""ell producing dry gas @ 10\'" rate. ' Rcv. out gas-no \,1:r. entry. Pooh 1,/ nTIS, tool. fD mt. ret. @ 9879' & Pooh \,-/ SarlC. Inst(1l1cd ~~atco test production sepcrator. TII! \"/ 1)ST tool, to production test the ;1-4 Sand perfs from 10,028' to 10,036' and fron 10,080' to 10,092'. (Footage 0') Corp1cted TIll w/ DST tool to prod. test D-4 Sds. perfs. fro~ 10,028' to 10,036' & from 10,080' to 10,092'. Set tool G 10,020' (tail of tool @ 10,041') Charged dry DP \,'/ 2100 psi. Opened test tool G 3:14 an, 1 surface shut-in for 10 miTIs. ¡.:o inc. on DP press. Opened ','cll on 1/4" choke @ 3:24 am for 20 mills, IFP. 51 \\el1 \,'/ 1000 psi on DP.(2 3:54 m:1 for 1 hrs. 15IP. Re-opcned \\'e11 @ 4: 56 aI'l for 2 hrs. final f1O1\'. Blcccl surface press. to 0 psi by 5:45 am. Left open until 6:57 am. SI for 2 hr 0 final shut-in period. Pooh. Ree. 210' or 1 1/2 bbIs of rathole fluid a}~o' tool. 4 1/2 hrs. rig repairs. (new clutch high & 10 f¡ ne,., hrake blocks). Spotted perf. pill from 10,200' to 9500'. DST #3 Pressures: II ll-I Open Tool IFP , ISIP Rq-opened tool , FFP FSIP 4559 psi 2700 psi 1192 psi-30 mins. 2676 psi-l hr. .. 1192 psi 122 psi-2 hrs. 2338 psi-2 hrs. (Footage 0') Mixed 68.8# Drill "S" pill & spotted across perf interval 10,200' to 9500' (35 bbls). RU Go-Int. & repert. D-4 Slls. fron lO,()26' to 10,038' & from 10,076' to 10,094' i\/ 4" egg. glID Q 4 hpf. Ran 7" ¡~OKCO IS tool 1t4. Set tool @ 10,018' (tail @ 10,039') Ch~rp;ed Dr \4 2173 psi gas press. Opened too! @ 10:57 aJ1 \,i surface valve closed. No press. inc. on surface. Opened surface valve G 11:00 am to flare. 51 \\'ell G 11:50 am (1st flO1'¡ period) ,,/ 200 psi (ISIP). Re-opened '\'ell @ 12: 32 pm for finnl flow period. Irad light blow for 3 hrs. 3:30 pm 51 Hell for fif'"ll press. build-up. Pulled tester loose @ 7:30 pm. Pooh. Ree. 420' or 3.1 obIs of fluid (\<ltr) in DP.. DST #4 Pressures: . .II n-I Opened Tool IFP ¡SIP Re-opened töo1 FFP FSIP FInl 4540 psi 2674 psi 344 psi-30 mins. 2282 psi-I hr. 148 psi 221 psi-3 hrs. 2159 psi-4 hrs. 4540 psi 10,522'TD (FootaEc 0') RU Seh1umberger. Ran C:L-Dcnsity Lot; fro;rl 10,300t to 4300'. 9,750'LTl R.1.H CEL-VD Log from 10,300' to 5790'. Set Baker ;[oc!c1 "K" ant. rot. on \'.1J @ 9950'. Set Baker rrode1 "k" emt. rete on \'.1. Q 9750'. (isolate (¡ squeeze 1)-3 & D-4 sds.) I~an Yet. stinger on 3 1/2" DP to 9750'. 10,522'1']) S, 290' 1:1"1 (footage 0') Set into Cr.lt. rot @ 9750'. Broke Ù'IÌl. fm. Q 2200' p:::i. PI @ 5 cfm. f,lixcd 150 sx. Class "G" OT!t. \0;/ .6~ D-31, .5~ D-10 [! l~) D-36 (clcfoam.) Initi~I PI wI emt. S cfm '.1 1800 psi. FÌ1~al PI.:; efn ) 40nr psi. (squeczed 140 ef. cnt.) Pev. out 32 cf C"..f.lt. Pooh. PU ~~chl11:'ì!'('rr('T. ¡tom B~¡J~er ~lodcl ilK" cmt. rate [I set Q 8::90'. Perf. U!)per T)'onc~~~ ~:~J:;. froi' 82115' to 82:;~' ',:1 <1" CS~~. run Q 4 11p£ for j)ST ItS. n,;m 7" 1);;]' .I!5. ,t'('t ton! ,)"'17' «(' (,1"'11,(,.,(",1 "/ .,17rJ"¡)l.,'lo' 'T'lt: 1)1"""'" ""'>,)('11"(1 t'Ao' ') o;;,,]? 1)"\ "'I' ",""("'1,'-(' C1( ,.... ¡,,'..,"'..... ",,1,' '~","'. \", .\:"",.,_1. """'-"'" ¡JI'C""" 1"'1."' C';., <:111,¡"'I"'('. t'() ì,I'~;~) 1"'1' (\')"'..'l;"o¡ <'I'y'J"ll'" lì '~)""I) :11\ 1')1""l.'11¡ ,<'(,11J ,'..).,J,.."JI,' ",.,' '"~'.',',. ',I.,.v",. ",\,"""""'. ,I, 0'.. to '1:25 1)1:1",'/ cIcco in press. to :)OD psi for.1st f1m: pC'.rint!'. ;~I 1-',~o11 :: 4:2;' pm for ISIP. J~c-opcTlccl tool 0 (1:15 pm for 2 ncl 11m' pC'.ri()d. J'lol..'C'dH 2 1/2 hI's., Q 1.(1S !':ì'1cf/d ,oJ 300 psi surf<lcc press. (no ",tl'. cntry) ~;I "'1"]1 8:3:' pm [or I:~;IP. ' W\~L nL\T~ 8/S/i4 . 8/6/74 8/7/74 ~ KI~~\I rr' Fõ1) 10,522 '11) S,290'LTD 10,522'TD 8,290'ETD 10,522 'T!) S,1S5'ETD IT \.lLL I:u. H'") (.': " '- - FILLD Kenai"Cas Field D~TfÎILS CF CPE:'...\T1C¡;S, ~C:'S ~: RESULTS (rootage 0') ~ev. circ. ~as cut rruù out of Dr & annulus thru circ. sub 'J l!ST tool 51 for fin<11 51 period. Leveled fluid Kt. out :~ 69#1 cu. ft. ., 1 d 1 ~ 6 -" P . . l' 1 100' . C T)p hC C<1SC too ¿ :.)\j X:1. rcss. Inc. lJT':f1CUlate y to pSI on esp,. <.:¡.. Raised fluit! "L. to ïl::/ cu. ft. & rev. out gas cut fluid. Press. iJ1c. to 400 psi on Dr & esr.. Inc. fluid "L. to 73#/ cu. ft. Disp1. csg. 3l11lUl1l5 Bullhcaded 73# fluid fror.l cire.sub @ 3186' to perfs @ 8245' to 8255'. Ci: 73# fluid up Dr holding 300 psi liaek press. Bleed off Dr & annulus. Opened hyd. 4 circ. armmd 73# fluid. DST #5 Pressures: Il~ 3386 psi IFP 2601 psi FFP 467 psi ISIP 3950 psi IFP 786 psi FFP 516 psi 5SIP 4049 psi (Footage 0') Comp. Pooh w/ DST # 5. TIE \~'/ 6" bit C¡ 7" csg. scraper. Tagged briùf,c G 8201' above pcrfs fron 8245' to ~255'. Picked up to 8131'. Circ. 4 condo fluid to 73ft/ cu. ft. Pooh. Han 7" RTT5 tool '~l 60' of 2 3/8" tbg. tail. ¡':ashed out fill in hole fron 8201' to 8272'. Set nITS tool G 8134', tail 0 8198'. Rigged up sqz. manifold. Cire. & condo gas cu" . fluid to 73#/ cu. ft. (Foota~:c 0') COf:~p. circ. out gas cut mUd. RTIS tool set @ 8134', 'tl¡g. t';Ü 03198'. P-cc. sand (¡ salt fron ratholc belm" perfs on Dtns. U!). PtE;:¡ed into perfs fonn 8245' to 8255', 2 cu. ft../r:;in (j. 2900 psi. Inc. prcss. to 3200 psi ~ fracto fona. . Pumped in @ :3 cu. ft./min. @ 2900 psi. Opened pcrf s to sur face t 11 TII Dr. No £101\- or prc s s . inc. in 2 hrs. Ran 1'1.. OlecL tbg. tail Q 8196', fill @ 8273'. ~\o indication of gas entry or flO\':. Released I~TTS tool. Pooh. Sct IIO1\"Co r:sv mt. ret. on \'.1- @ 3135 I. TIP ""¡ ret. stin~er on DP. Stahbed into ret. -l'h~cah"h\11. of 10 cu. ft.i:r,in Q 2900 P Pulled out of ret. Pur;pecl 56 cu. ft. of ,..rtr. ahead () behind emt. Ptlr1ped 150 sX. '4 "G" wI .6% D-31, .5% D-19 [¡ l~J by Kt. of \\'tr. of D-6. Pt.!r:1!cd 56 cu. ft. of salt 'i\tr. Closed tool. Displ. ,\'j 240 cu. ft. Iì.mp ratc of 5 cu. ~t./min. @' 3600 psi final SI stcmding press. of 3250'. Pulled out of rat. , . " , , \ 1 " .. ~ ~,..,.~ ~ '~~c '?(. :.',,?,~,;"':"':;';::~:~~:':'":.:. ::~.' '. ..'~ . ~:::, ~~~:~~:::~r~::~.. ~:'~~:;=:'=~,~~~.~~~ -~~-i' ~~'.~'~-;'~-~'~~1'~' ,,~~.~~':,"~,~, ~~.~,; PR':PA"F.u FOR , .,p~"", TEL.EP"ONE uATE r . , MR. DEPTH --._---------- FIELD "AME ..... I Ï t f Î 1:; " ~ I A ~ 5'8 ='èt L~DU ( ) ~A?T ICCr.C?. .:::-=-- Fee lOt,' 0 NEW 0 COMPLETION WORKOVER DEPTH CASING LINER 0 ?AFETY EQUIPMENT 0 GAS LIFT EQUIPMENT OPACKERS AND ACCESSOR~ES OCOMPLETION EQUIPMENT 0 POST COMPLETION EQUIPMENT DESCRIPTION OF EQUIPMENT AND SERVICES ESTIMATE <:.D ~ = ~ ¡<eN:":" ~ -ìt::Ld (yò f 0 ~ ~ c:J 'R...e .:. ONJ9U" 11().rJ 5'0 $"0 '15/B I' Du ~L H I.i dVA\.U..ì Co tpYu c.lu.,..:íJ' o..J . P A Qe.Ye.. G. .5"05'"0' :5Tl""K t I^,,; pr'}O I '(~.. 'P6:t.....ls- ~;~' :LOS"D - > . "1":c,-,,,.) D I L P'" +tJv"lTltJ"JS '51 ~ 8 - 5",1 30~ I 51'70- ~ î 51 '3 S'" - 5 ':J '-5" . 5"¥Co c¡ 51'?," <;'1:"'. t-I, AVA"4l ìr PA:. ~ ~¡.e T~oLÂTIf)N ~ D.sT fe\.<.Js R:;2.4-S"- ~G.SS' S~I' ~ ~71!d '-"'/, So ~ "{;.." ~A1"- TjoN€'t::.. D--z. "Z.ð,vc:. f"'~L'¡:c,- '1510-'15'2"2.' VIi- QS5'B-9S8S' DX!.. p v 0 J........ Co "\'", 0 .N TOTAL ESTIMATE COMPLETION PROCEDURE .s~ I..l ~ ~.4r.e.J. .:fs.i:>I,..I'ÌT~J --.---.-. ¡OFFICE l TE~ÚH"õÑË'-- DATE ."-.-..--'. .. 10 \0 52? WË.~L NAME FIELD NAME ( i { C 0 p y DIVISION OF OIL AND GAS March 17, 1969 Mr. Robert T. Anderson Union Oi 1 Company of California 2805 Denali Street Anchorage, Alaska 99503 Dear Sir: A review of well data on certain wells drilled and completed by you indicates that there are some deficiencies in required data; these are listed below. Kenai Unit No.2 Deep No electric logs have been fi led and there is but one copy of the chronological well history. Kenai Un i t Well-No.4 3-6f\ No electric logs and but one copy 6f the chronological well are on file. Kenai Unit Well No. 44-30 The required sepia copy Qf the electric log has not been filed and there is but one copy of the chronological well history. It would be greatly appreciated if these deficiencies could be corrected as soon as possible so that these well records will be complete. Very truly yours, Homer L. Burrell Di rector H L B : RE L : j a ~ ,I ( UIVISION OF OIL f\UD GAS Janua ry 21, 1969 Re: Kenai Deep Unit No.2 Union Oil Company of California, Of)erator Mr. ß. E. Talley District Drilling Superintendent Union Oil Company of California 507 vl.. Northern lights Boulevard Anchorage, Alaska 99503 ' ~ Dear Sir: EDelosed is an ;approved copy of Sundry Noti ce ." (P-3) for the above referenced ~Je 11 .. Very truly yours, .. ' "',.' '¡" ,.. // ./ , <~¿~~:,/' /', ' i f,'~ ,,"" ,1"'".,.,-,, ' """-<-" /1 ",.1./ \ (/ Karl L.. VondcrAhe Petroleum Engineer KL V ;¡nay Enclosur.e I~ Form P-3 REV. 9-30-67 It Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate V-- {¿(¡:J 5. API NU1VlERICAL CODE OIL AND GAS CONSERVATION COMMITTEE 50-133-20121 6. LEASE DESIGNATION AND SERIAL NO. SUNDRY NOTIC'ES AND REPORTS O'N WELLS Anchorage, 028142 (Do not use this form for proposals to dl'ill or to deepen or plug back to a diffierent reservoir. Use "APPLICATION FOR PERMIT-" for such proposals.) 1. 7. IF INDIAN, ALLOTTEE OR TRIBE NAME OIL 0 GAS ex WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT, FAR.l\i OR LEASE NAME Union Oil Company of California Kenai Unit 3. ADDRESS OF OPERATOR 9. WELL NO. 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 KDU 112 (21-8) 4. LOCATION OF WELL 10. FIELD AND POOL, OR WILDCAT At surface 337'S & 4274'E from NW corner Section 7, Kenai Gas Field T4N, R1lW, SM. 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 8, T4N, R11W, SM. 13. ELEVATIONS (Show whether DF, RT, GR, etc. 12. PERMIT NO. STATE OF ALASKA M. 92'RT I 68-49 Check Appropriate Box To Ilnd:i'cate Nlature of N~ti'ce, Relport, olrOlther 'DIC)ta NOTICID OF INTIDNTION TO: SHOOT OR ACIDIZID MULTIPLID COMPLETE ABANDON. SUBSEQUENT RIDPOBT OF: WATER SIIUT-OFF § REPAIRING WELL FRACTURE TRIDATMENT ALTERING CASING SHOOTING on ACIDIZING. ABANDON MIDN'T. (Other) correct b hole location (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) detail", and g-Ive pertinent dates, Including estimated dat~ of starting an~' TEST WATER SHUT-OFF FRACTCRE TREAT PVLL OR ALTER CASI~G REPAIR WELL CHANGID PLA1JS ( Other) 15. D~:SCRIBE PROPOSED OR CO~IPLETED OPERATIO:-IS (Cleal'ly state all pprtlnent proposed work. To correct well location at top of producing zone and at total depth which was erroneously reported on original well completion report. Corrected Location: At Top of Producing Interval: 132' South & 2640' East of Surface Location. 119' South & 2605' East of Surface Location At Total Depth: RECEiVED JAN 2 0 1969 DIViSiON OF Oil AND GAS ANCHOR/".GE .16. I hereby cert ) TITLE Dist. Dr1g. Supt. DATE 1/17/69 SIGNED TITI;m u. ? - DATE t/2~ /1 ¡: .' .". See 1,n,strucfions On Reverse S,ide r,".' ( Union Oil Company (' ~alìfornia /) ø -' 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 ~ Telephone (907) 277-1401 ¡í#-J ,..' I" '1-.-- ,I I ¡...c." un.en January 9, 1969 Mr. Thomas R. Marshall, Jr. State Petroleum Supervisor Division of Mines and Minerals 3001 Porcupine Drive Anchorage, Alaska Dear Mr. Marshall: Attached is the initial 4-Point Potential Test for the interval 9896'-10,522 (TVD) in our KDU Well No.2, Kenai Gas Field. A copy of the subsurface pressure report is also attached for your information. The four flow tests were conducted using the isochronal method. <" The well was shut-in for approximately 60 hours to build up. The flow rates and pressures reported were taken at the beginning (just before opening for flow) and at the end (just before closing in) of the 60 minute intervals. As a check on accuracy of this method, flow tests on 15, 30 and 45 minute cycles were computed from data collected during the tests. The results were identical with the 60 minute cycles. This indicates the well stabilized during the first 15 minutes of each cycle. If you have any questions about the test results or method used, please let us know. Yours very truly, ð % /,/~ / " ¿~ :' E. Ch~rch Production" Engineer JEC:mgl Enclosure cc: R. C. Hartmann Elmer Kendall Bill Spradlin Juan Pedretti RECEIVED JAN 1 3 1969 DIVISION OF OIL AND GAS ANCHORAGE FORM 401-ANC-W (8/67) GAS 'Iv LLL OPEN FLOW POTENTIAL TEST RE:. ..JRT 4-POI~T TEST Test (Isochronal) D Special 0 [X] Annual Initial. K i I Reservoir I Test Date ena Gas Field Deep Unit~ 0-3 & 4,Sands 12-27-68 Lease ¡Well Xo. CO. of California Anchorage, 028142 KDU-2 Location Top Prod. Interaal: S439' & E6830' from Completion Date 19r¿t~~ePi{}? IT/Pay NW Corn., Sec. 7, T4N, R11W 8M 8-21-68, 46' Producing- Thru I Reservoir I ",'ellhead \ egG. Size I '\\"t/Ft. J.D. I Set@ 10092 MD _~BG I CSG Temperature Temperature X' . 160 OF 58-74F 9-5/8/7' 40/29 9-5/8 to 6026': 7" Liner 5821-10,522 TBG. Siz,e I Wt/Ft. O,D. I J.D. I Set@ J Gas Gravity I Mg. Prod. I GL I Gas-Liquid HYdrOCar,bon I Gravity of (Separator) Length (1) Rat 10 :l1(,F per Bbl. Liquid (Api) 3-1/211 9.2 3.5, 2.992 9859 M .555 9824 5452 333,000 25 o Pipeline Connection I TYPepTlaaPns fYjUa,' ,,;:"i".'., 20" Kenai Nikiski Pipeline 5~~.r1 :Multiple Completion (Dual or Triple) I Type production from each zone Single with 2 Packers Gas OBSERVED DATA Flow Data ¡"ield Casing Press. , psig Flowing Temp. of Tubing Press. pslg Press. , 9990'MD psig" Diff. h Time (Prover) Xo. of Flow (LIne) Hours Size ST 62 1. ]. 3. 52 2. 1 3.152 3. 1 3.152 4. 1 3.152 Coeffi- -Vhw No. cient (24 Hr.) 1. 28.9168 151 2. 28.916& 229 3. 341 4. 426 (Chol,e) (Orifice) Size w 2.250 2.250 2.250 2.250 FLOW CALCULA TIO~S Gravity Factor F g Compress. ¡'"'actor F pV Flow Temp, Factor F t Rate of Flow Q MCF /D Pressure psia p m .9442 .9611 .9569 .9551 l3423 1.3423 1.3423 1.3423 2 2258 2126 PRI<~sseRE CALCULATIONS , p P W p:! FQ (F Q)2 (F Q)2 X 1- e-s p2 p2 - p2 Cat. w - (p¡.;ia) p - p :t c c c w c w w P t c 1. See A ttACJ:.t IS d 2. ~. 4, In l\ICF/D Ahsolute Potential 103,000 O. 791 CERTIFICATE: I, the undersigned, state that I am th~ of theUniOTt Oi1 r.Ó - of Calif. (company), and that I am authorized by said company to make this report; and that this report was pre- " pared under my supervision and direction and that the factrs S,.,}ted the", r",,:'" are tru~,',.'~"..7c.o" r, ,~/5~nd comp",)ete to the best of my knowledge. d~" "~,, ' ~ , /' ,.' ///' ,," ) ,,<;Í'~/l ,<L-.A' r'" j; , ........" \....--~--_..".......... Sign ure / " IICEMD JAN 13 1969 Alaska on and Gas Conservation Commission Gas Well Open Flow Potential Test Report (4-Point Test) Form No. G.I Authorized by Order No. I DiViSiON OF on. ~~\) ~Mï ANGI'4Wi2JE Effective October I, 1958 0" .J. If) " (\ , -... , ," C'I, 10 (f') I.;f r: ~~ U '~ 'J it') - I., ; ., ~ - , cr L.: " ,\ I., e: ~) Ow ..J '" 'lJU I.:~ )\ " /' 'C ' 1 2 3 4 , ~ ' : ¡ ~:-L-~~~'¡~ : . ¡ " ! ,'"I,,',,' 7doÞ -.-J - ' " ~ J:.., : - I ' I ¡ , ,.i. t I ~--~__,_L...+~ Þ.->r:-+t- -+ '" I~:" ,':Ie: + --J-~+-£~i}--- ,- ~I- L:.. '.---r- ',' '.. :"..,' ;!_C -.-1-< " '_~~_i- cri- -i--: un _n __~n~__-'~+-"':C-,'.: \{t,;':- :,:-,~ '-e; '" ,'," ,> I" 'I" )1 'i",!1 '" ",,¡::;::,::P,::,':,', ;, I " " ", L --~---- -' -1-- - "Pws .¡:- 41. pliO' RiCEd Jo3 1969 5 6 1 8 9 ,10 20 3J 40 " ' .. , 'J J_,~: "::' :-:'~;-:fI!:;~:,ê~,:;: >', i .. - - ,- - , , " , "-,-, ,.. , -" , , - , ..-.. .. I I-' , , ': I' : : '~F!"-':'¡-: , .. ~ '~-:---~-:-t-~' ': , -..:.-- I ' , , " -, , _.. , .. , , .. , , , , , , , .., .', , ,c ,. '; , r; I . ' ',- ----,. --,-,- " ¡, ' , , : . " , 1~:L:' .:- ._>~UL- :'! , 't I "~ '" 0 II) a. , " ~',:,'~~ : ~~, J~" ,,'1, '~~ "', t, " .. ..; . , , ' , ,- -" . , , I' : ,I ,.., -----""-' --,--..,-.. .. , I I I I , ' : -:"~--~k- --- ?t~ ::'!:' i~-:+~ '" , , - , ..,.., , , ' ~ , '-' --..:;.. , ",' ----- "t. " , I" N '+- ~ Q , . l' t '.,..--:- .. I '--' ,::~ , .." , " : ~7t- , ' I ; l' ' ! I : : ! I i :"~ :!" " " ;"" '." J :- - I " , J ,--_:...:~,_:,L,' I.. ':', FIGURE UN ION OIL COMPANY OF CALI FORNIA PACIFIC COAST DIVISION ALASKA 018 TRICT KENAI GAS FIELD J -- ---.. DELIVERABILI TY AT THE 5;t¡VD J=74C5 ,.. I ,: ----,-4---,..- I ,'" i I I ' - --.....- -.. '-j" ¡ WELL NO,. I<l:)iJ -.:< (~/-a) ? ( : MODUL E : p- 3""~ 5ar1dS (L (,..¡"". I ",,'r:,) 0, ¡TISC F/D = (Pws2 - PWf2 ) INTE~PRETATION BY SCAL.E DATE; DRAWN BY , , . I I I, i: , 1 ' lð i 1- ¡ I ! 1 3 5 FLOW RATE, Q, mmscF IOay .' ( " , ( 1/ - ( ~; t " .. . GAS WELL OPEN FLOW POTENTIAL TEST REPORT PRESSURE CALCULATIONS (Supplement to Alaska'O & GCC Form No. G-l), Field Reservoir. Deep Unit Lease No. Anch 03& 4 . Kenai r,as Fie ld Operator . Union Oil Co. of California Î Test Date 12-27-6S Well No. , #? Surface Test Data '- (1) (2) (3) (41 j Test ,Ps Pf (Pws 2 -Pwf2) Q No. Psia Psia X 10 -1 MCF/D 1 3380 ~32S 36.88 5921 2 3378 3252 83.54 9226 3 '3378 3102 178.85 13679 4 ?C)Qn '.1 R A ~ 17056 ""XII " S " - Sub-Surface Test Data ~ - (Isochronal) æl .> 0 Subsurface p-ressures measured. (See Attached)' '. . . Subsurface pressures computed: Cullender-Smi th t.tethod of IDee. (1) (2) (3) (4) (S) -~ Test Pws Q Ptf Pwf (pws2_p\,¡f2) No. Psia MCF/D psia Psia X 10-4 : . t 4133 5921 3325 4080 43.53 - 2 4133 9226 3252 40~0 Rð, n,R --. 4127 - , 13679 310¿ -3960 135.05 .. .) 4 4121. 17056 ?qQO. 3910 1694S 5 Nomenclature: ... . , " Ps = Static Flow String Pressure Pf = Flowing Flo~ String Pressure, Pws = Static bottom-hole pressure (mid-point of perforations) 'Pwf"= Flowing bottom-h91e pressure (mid-point of perforations) , Q = FlO,W rate, ~lqpe,r',da,Y,at"6"o~Fla~d,, 14.6S,~,Sl,.j:,~. ',; ~,.,.uRlëIIVID -, -~ ¿t- "", ,', """,," -, "-,--"-.. ", ", JAN ,H,i9B9~_;,- ,'".,,;,'.~:- ,.., ' , øt~~~u/ioli!i,' ~ ~, .fj¡Â§ . A~:GJ=.' , . . . , .. " . .- , " I, ,,-' , ' '\", ,<i. ',' ,",'"" " ~¿,.~; ;..:.."""(~;,;",,,,",;;;...:.,--- _.,~~~""" '""'" 12!iL;;..~,I;:i¡'_~~I,,""""">:';V'II.""'1IJ:II: ~........._'.... - ....,,"'>;. .12\....""""-..,, ,~;.:ø,:JoI4:J'¿- ",",~~~.,~~....~~,~..., -'. ~""..........."......,- ~... <. ..0" ...-. \ it E. G. MYERS WIRE LINE SERVICE ,'I' ( ~'""""III"""'";;o;¡., ""~:i!\""""""":"':""'I"""'l,~.'r,, i" ".tfrr.,\,.,"':,¡~,:"::" in J'lft- ;..~'" ' '~~'..,' .fj"-'-'" '",;:";~,: . ' ",' "~, G; .-l 'lr[.,~,1; :""':""""'\"ñ,"""" ,~_: '. I'. VI c:- kêf:~~~ " . "', " ,.. -" ",J, ' , (" ....1 r'~ ¡ \ ì .' j , r ! P.o. Box 57 Kenai ,Alaska 283-7819 SUBSURFACE SURVEY Field Work Sheet 99611 t ~ . ¡ ~ j OWNER UNTON OIL CO,. - . FIELD Kenai Gas Field WELL NAME: K D U Ë CASING 7" , ----.- E"~-V-:- -'-'--'------------~¡TE 12-_22~6-fl_- UNER DESCRIPTION --Perfs. '9}\~_' -' lOÕ92'--=_~_.~=-~=' --,-------- ZERO POINT 12 t DEPTH 9930 ' ZONe: Middle Ken.!ti D Zone TUBING DETAIL }}". Otis x~ ~~ïe~ves -93W~-9448 '-, 9?~2', Otis Q nipP!~ 9822', end of \'.:!þ.?:.ng 9R58'. --~._-- - .---,-------- -,-"'-" -- 4 pQl!'1 t te st -- --. -- --..----- PURPOSE REMARKS ,--_..,. ' -'-'-'------' EL.£MENT 58001 SERIALNO..K,-::'? 4212 CLOCK :1.2 2-1 TURN ENGA.Ge: STYLUS 10 :l-Í-a. m. DISENGAG£ STY~=-.f..;.QO a. ro. 12-28=bR" OBS. TaG. PRESS. 3380#=____- -..-_--_--_OB5. CS~~ES~:...--_._---, COR, TaG. PRESS. 336 5~_.___-,-,--. --- COR. CSG. PRESS. ~ICKU£,~. TIME ON~ò;TTo_~_lJ :J=..5._a~!!l...!.- -- ,.----.------ 160Ò -,.-----.----- MAX. of WEI..I.. STATUS Sta t ic SHUT IN 9 :_OÕ--p-~.~. '] 2-24="6"8 STABILIZATION PERIOD ~ -"'- _._------ -.-- -- -_..---- - -.-.---..... GROSS OIl.. RATE B/D ---.-..---- ,ON PRODUCTION NET OIL RATE BID ill...shv,.t.. ~n for 60-.-h!:J~~:.\n'!"=="7"-===-----'--='" . =-. FORMATION GAS MeFfe. ~~n1~e:i~~~.i ¡1~1;:: r ~~.-..~~.-.ffw:.H~IC~~'li%z..2 -=X/o 1. :::::::LGA¿";;F¡;;-.--~~- ---:1:- 4Lhrf-2Q.Il._L4J 4.Q2: ~ OILO.. GRAVITY "-"'---.- S. I . W. H. LJ~, - ' i 2..hr 2290 1.41 40 : !_~~N SiZe: . -.---.-- 5 miq9~~-~)O11.r¡2 i 118 2 h ~ 5~,~_- "-+1...41 - 40 '. ¡ ¡ CA,,~ING PR!-~---_..- " " -+-. --. . '---.. r-.-';:;7j, '- ", ~-~-- J !U8ING PRESSU.~.§...,,-,-,_.. :~:ft~b ~~ l----- t~--~ =-~t.. -t --L-J ~~~ ~~~¿,~ Œ^OIENT 1 hr 929itp:Iï2 I - 1 . '-=~~~-, :~-l.. -,---r- . -j.- ----:':f-=-- il~~ .~~~f9~~~-T"+ "1". .1 ! i_==t==t-+. s.r:tw.H.1 P.-hw --+--.---f-- I ¡ "~ 1 h~2.t2f-l~ 4 ~ : --'-~ L:i-_-=: i "1 F o~~~---- -jQ161fJ Bean -.-'f .: ---t- ----.j-1 'ffi ----I ! S'~~~9~ta~)O . t~-;¡:.~f- ! 1- ~- .=i==t . . ~t~ì~~~2 --==~ . ~~~ ~ :c ~1~~1~~ _. , 1 ~==f ~ t~_.::¥- COMMENTS: , (~~~- 1 hr .,° '. l.. Off bottom @ lOllS p.m. Instrument 42001 K-2 3402, did not have ø'ood cralêEIVID. JAN 1 ~. 10~O BY:___. Myers . Ð'lrt1~~ G't C§I~. AM9 (j¡J.§ '°. .--.. ._---_..._----_._-_.__._.._,_.._.,_..,----__,~~~êt- \ Form P 7 , ~h ~ ~' t/,,>, " l,,~, "I' .. - SUBMIT IN DTJPUC!Í. n." ,"', 'i' STATE OF ALASKA (~-'l'othcrln- st rul't ion~ on 5. API NUMERICAL CODE reverse side) OIL AND GAS CONSERVATION COMMITTEE 50-133-20121 ,-- COMPLETION OR RECOMPLETION REPORT AND LOG* 6. LEASE DESIGN ATlON AND S:E:RIAL NO, WELL Anchorage 028142 " la. TYPE OF WELL: 011. 0 <.;AS ex DRY 0 7. IF INDIAN, ALLOTTEE OR TRIBE NAME WELL WELL Other b. TYPE OF COMPLETION: NEW IXJ wonK 0 DEEP- 0 PLU<.; 0 PIFF. 0 8. UNIT,FARM OR LEASE NAME WELL 0 n: II EN DACK r.ESVR. Otbfir 2. NAME OF OPERATOR Kenai Unit Union Oil C~mpan,Y of CalifÇ>rnia 9. WELL NO. ", .. . 3. ADDRESS OF OPERAToa Kenai Deep Unit H2 (21 507 W. Northern Lights Blvd., Anchorage, Alaska ,99.503 10. FIELD AND POOL; OR WILDCAT 4. LOCATION OF WELL (Report location clearly and in accordance with anJi StŒte requirements)- Kenai Gas Field At surface R~f~r\ir?J 11. SEC., T., R., M., (BOTI'OM HOLE ,'~~::':;",",:.::...",íil." OBJECTIVE) At top prod. Interval reported below DEC 27 ,07 ') Sec. 8, T4N, RI1W,' SM. t:" 'I " At total depth DIVISION Of OIL AND GAS 12. PERMIT NO. 'ANCHOfi,'(:Je 6ß-49 " , " '", 13. DATE SPUDDED 14. DATE T.D. REA;CHED 15. DATE COMP,SUSP.OR ABAND. 16. ELEVATIONS {DF. RKB, RT, GR"~).117. ELEv. CASINGHEAD l)-7-~<6 C6 '-d.-( --f¿f' ,'~," , 18; TCYI'AL DEPTH, MD & TVD 9. PLUGB.ACK MD & ~.- w. IF MULT.lJPLE COMPL., "" 21. INTERVALS DRILLED BY DEPTH HOW MANY.: ROTARY TOOLS CABLE TOOl.S " 22; PRODUCING INTERVAL(S) , OF THIS COMPLETIOiN-'rOiP, BOTrOM, NAME (M1), AND TVD)* 2~. WAS DIRECTIONAL " SURVEY MADE I' I 'f ),/, ,11/", , " K- I -8) I 24. TYPE ELECTRIC AND OTHER LOGS RUN 25, CASING RECORD (Report all strings set in wc;U) , ", ,I CASING SIZE WEIGHT, LB/FT. GRADE DEPTH SET, (MD) HOLE SIZE CEl\1ENTING RECORD AMOUNT PULLED , I , , , "" L , , ," I " I '" .\: 26. LINER RECORii¡> " 27. TUBING RECORD ' "I, .. :iÐOTrOM (MD) DEPTH SET (MD) , SIZE TOP (MD) " SACKS CEMENT. SCREEN (MD) SIZE , PACKER SET (MD) , I " "'- ',I' ," ',' " , ,,'," 28. PERFORATIONS OPEN TO PRODtrC!I'ION (Interval, size and number) 2Ð. ACID, SHOT¡F:ctAC'T'URE, CEMENT SQUEEZE, ETC. " 1 AMOUNT I~D,KIND Q'F MAT1!:RlA1;,. USED " DEPTH INTERV AL(MD L, " " " ,¡ ' .. , ,': ,I ',;' , '" " 30. I DATE FIRST PRODUCTION 11/30/68 PRODUCTION PRODUCTION METHOD (Flowill.g, gas lift, pumping-size and type ofpwnp) " Flowing WELL STATUS (Produclngor silut-in) Producing , DATE OF TtST, HOURS TESTED' CHOKE SIZE PROD'N FOR TEST PERIOD 11/30/68 5, Variable .. FLÔW TUBING CASING PRESSURE CALCULATED OIL-BBL. PRESS. c' I'; 21:-HOUR RATE ; 3280 -, . 1. DISPOSITION OF GAS (Sold. uBed jor ueZ. vented. etc.) OIL-BEL. GAS-MCF. i 2882 W ATElV-BBL. , GAS,-OIL RATIO' -, GAS-MCF. 13,824 W A TER----BBL. OIL GRAVITY.API (CQRR.) TEST WITNESS~D BY Sold - Kenai ~ik:i.'~ki Pipeline 32. LIST OF ATTACHMENTS' E. P. Kendall Bone TITLE Diet. Prod. Supt. DATE 12/26/68 3 . , *(See Instructions and Spaces For Additional Data on Reverse Side) ."~', "'" "", r , ¿~, ,..' 'i.J. ,\04 "'"" ...' " "r"O 0 , . ..-- ,-., ~ ,'~, ',.' " ;,.( ,-, INSTRUCTIONS " " 'v ""-' General: This form is designed for submitting a complete and correct well completion report and !Qg on all tYp'es of lands and leases in Alaska. ". Item:;';16: Indicate which elevation is used as reference (where not otherwise shown)-'for dep!:h mëâsure- ment~~given in ether spaces on this form and in any attachments, . ",' '-~ '~-~ ,:;-- Items~~O, and 22:: If this well is completed for separate production from more than one il1!erval'i zon~' (multiple completion). so" state in item 20, and in item 22 show the prcducìng interval, or'" il1t~"rvals'~'~ 'top(sL bottom(s) and name (s) (if any) for only the interval reported in item 30, ~':,Submit a sep~rate ~eporF (page) on this form, adequately identified, for each additional inter val to be seperateJy prod~ed, ;Show~ jng the additional data pertinent to such intérval. ,,',-,' Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. , '. " .' -.. " . , '~em 28: Submit a separate completion report on this form for each interval to be separately produced. ,-,,' (See instruction for items 20 and 22 above). ':~ "'- ~r,~ ~'" roo MMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL GAS ,'" : ", , ' . '-., WATER 'AND MUD 1..;. " :'" , ~',~:', ,-"; 35, NAME ~: ç;. f.~ ',: c: ~:; :'~ ,.; CJ., ~:,. h' "'.;'; ~ <¡ ..-. " ;.",. ,~ r, ""', ¡.¡ V .:c.;; .;;.¡ 0 ;-., :.;;,¡ ',-' ,'~..~ ", 36. CORE D1\.TA.' ATTACH BRIEF DESCRIPITIONS OF LITIiOLÒGY. POROSITY. FRACTURES. APPARENT DIPS ¡,', ' ¡"". AND DE'I'EC1'EI> SHOWS OF.' OIL, GAS OR WATER." -;-' i , ~::';" ".."" 't.C ' t~. i::::. r.., () :.. ~ ~"";: :'-,- :,:: "', "," , C", Co,', ,,~, ...e" /" ,"", "", , ' -- ," (',~ (,\:' '",." ¡, '~'" '-""" " ' ""e' 1""" I_,,^ "',. ", , .,,' GEOLOGIC MARKERS ~; ",,' " ~; MEAS, DEPTH. " '.', ~~ :> ~ ;..~ "', ".." ~;' , , ~;. . ."' "" I,..': 'c :-...1 , . r-" " ;-':, "" , ~ì' '.., J. " ' " ' ".. ,'", . ." . - 1,..' :--'" ,. .-:; ,.., ',.. >'" , , ..' ,. .(~ ~j , .. .". '--' .' . l.~ ;..¡ {.; (' ;'-.; ,'-, h' ~, , ..." .. '., ...' ..., a }o- " , ...."'1 .." , (": ,.., ,'" ~-, , I' ,. , , .' I ," . -. . c' " ",) ,- , \ ' \ " U'E VERT, DEPTH .' .,', >' ," 'l . '." trt:.::il " . .~ ,'~ I , UNITE( '~~'~~ES Form .Pl\ro~ed. Budset Bur,~au No. 42-R3SS.&. ... ' , i SUBMIT IN DUPLICATÈ~" (SI'I' otbl't ~ DEPARTM ENT' OF THE INTERIOR .. . ::.i: ï:wËÕiii(~Ñ iiiõ;ï -¡ Ñ ò-ŠËñiÀL"iõ: atruetinnø on reverie Iide J GEOLOG ICAL SU RVEY, ^n~~~r~~e O~O14? " -,-~:....L""-"':""'-"--"""" ... - OR RECO~~PLETION REPORT AND LOG* 8. It" I:'IIOIA:'II, ALI.OTTEE OR TRIBE ~ urE WELL COMPLETION - 180. TYPE OF WELI.: ull. 0 C;,\5 [) DRY 0 'I. l'IIIT AÇlcEt:)IE~T :CUrE WELL '" 1-:1.1. Otbl'r b. TYPE OF COJolPI.ETION: K . I' . t NEW ŒJ \\" UI~ Ii 0 In:t:r. 0 Pl,rG 0 PIFF. 0 -,~"ru_...::.1 - "'ICI.t. . 0"'-'" cs D.\r.K r.EIVR. Othrr S. Þ"AR)I OR Lt:.\SE :'IIo\)IE 2. "AM E-ÕF" õFËliÃ'¡:ö¡-- '\0 --1<-'=.1' .,.: n Eo' ø -l.....D1. ; t: " '. -~ ,I. Union Oil ~'r"','I.\Y or Cnlifltnda 9. WELL :CO. '" ':"," . 3. AnDRESS or OPI'.RÃTI)R ,-- '.. ~." f- 5')~ \0' """rt~"'.,. \ L"r-.hts "l,uj ~nl"'\('Ir'~ \1a~I.~ 10. I'IZLD A:CD POOL, OR "'ILt1CA't . ',-~"~~- ':":':"-=":'...'-':::....~---~-:..!..~-~ I' " '~'.,-= ~ -. '.""Co 4. LOCATIQ:'II 011' "'.~I L (Rc'pnrl lol:ation ch'orlll and bl IIccordrUlce with aflll Blale rc'l"iremcJlI8). KC:1.1 i GaR FiE'~"! "7'(. . l.?7.1.f¡: f !' ()'l1 T4N. At Iurfac. ~ .'r' cornet' S~ction 7, RIIW. S}I 11. IEC., T., B., X., Oil. BI.0CK A~~ Sl'C,"ZY .~....J .. ""I. L'oa"r t top prod. Inte..o' r...rt"; belo. S"Ut;1 J.02' [, E ~556 ~ of OR AREA. su~race 'Location At total dl"¡ltII 50'.!th 102' :.c t':~.st 2556' of Surface Loc~t1on Scc. 8~~~. !{~ 1\.;, S~! , -, 't ~ . 1140 ."""... '0, DATB IBICBD 12, COti~T'I OR 113. ITAn '1 , I-I 7 ~ ' I PABIIID - .. -=-,~"LJ.~ -_5:,!._-- 68-49 7/8/68 K(~¡'3 i l:orl'U¡;! Ala~kél 7/3/68 H!7¡~g '8121/68 92 SO 'iii:'TørAL"DBPiØ:MP-¡-ñü- i1:-ñüa:8ÃëKT~D:JiD.TYD ;122.-111' "niLTIPI.. COM PL., 123. INTI:IIVALS ROTARY TOOI,A CABLE TOOLS . HOW )IAN'I'.. 'DIlILLBD BY 10522-9896 10477 - 9851 " ~ I a-Tn I - . 14. PBtt'CINO ui7:ï.."iiV'Ãi.(8), ()FTH'rscuMi'i.¡-TIÕÑ-:::rõP.-¡õiTo"~, NA)IB (UD AND 'IVD). -,- ~25' WAS DIBEC'rIO~AL BeaVE'!' XADB ~ß)lO 92-10080 VU~!169-~!;57/}~!J9910-!j884 'V~9287-9261/!-11>9522-9510 VD8t$99-8SSi , MD1003ó-1OO:S "i)\)4! 3-9l~IJ5/:.t¡)9588-9558 VD,8965-893S Yes 26. '1'11'1: ILECTRIC A~D OTHER LOGS Rl'5 " 12'1. "'AB WELL CORED IHI.., Son~c, ¡:ODC, S:~~, tE~U - S1.clt'\o,~ll' s~mplcs 1'0 ~R. CASING RECOItD (Report all dr~ft'8 Ice ~" "ell) 1:'00BI:O;O BIÚ-'-- "'wEiõïi-i:ï.R./rT.-'" -'ö¡:p"ïr"iË'Ï'T:ii,õf'" --:--iiõi.i:-'iiii:--------cß"u¡¡iaiiRiëoRD A MOt':CT Pl'I.LED -- --- 13-3iti" 5':' .. 5 1317 1.7-1/2" 650 sacks 9 - 5TJ.1I 4'Õ- ----¡;lJ:l7 12-1/411 lOùO .' S~¡C 1\.8 . , 29. LINER RECORD 30. , BI18 7:0P ()tD) BOTTOM: (MD) BACKB cnn:N'1" BC'II8M (UD) BIZB - 7" 5821 1.052],' 1000 Perfs 3-1/2" -- --. T,(;BI~G RECORD DEPTH BII:1' (~ID) PACKER SET (XD) 9824 9859 * 9415 1. PII:RI'ORATION RI¡:CUBD \In.lerL'IJI. 8ilt ClJld nHulber) ~1D ' ' II. ACID. SH~, FRACTURE, CE1IE~T SQUEEZE, ETC. . - .. .---. 10092-10080 ", " " ' ' ., ,'" ,. DB~B INT.BVAL (MD) A~IOt:N'I AND KI:CD OF )lATEBIAL t'SED 10036-10028 ø , I -- 99]0-9884 1-r. 9588-9558 .. ' . t. 95'!2-~))lO /1..- . 1 , , , 83.' DA'IB I'IRST PBO~CCTIO5 PRODUCTION I p':õOC"c"iiõÑ'M"iii'IOD (Flowl"I1, l1a8 lilt, "UtllP~'-I~1'1 o"d "" 01 pump) I WELL 81'A1'l'B (Prod.cing or .h.t.~n) , T£"stin~ QAB-,)ICrr. ~'.\TER-BBI.. I GAS-OIL 1-"1'10, 'I WATE:R--BBL. lOlL GRAVITY..&Pf (CO...) - I 'I'E8'1. wrr:n~SED B'I' I Hor.. """leHO.. "". PLOW. TUBING r1tlS8. t'~.\iiiõ'PüiiRI:RE I CALCUI.A'IID 24"80U8 8AU I . ~ ãi":DIBI'OBITIOX 01' GAB (Bo£d, u8cd loriuel. vente';, eto,) I PROD'N. I'OR 'IB.or PBRI0D :. Oll.--BDI.. I DATI or TEsr OIL--BBL. CAB-IICI'. 3D. LIlT OP ATTACH)IENT8 ':" '- >, " , , " " 36. I hereby cel'Uf~ !:~,t t~. f.O}~õfñiãnd attached Information I,~ ~~Ple~:: an,d. eorr:et al deterlDlDed from aU annable recordll-- , /:" //t!/,II UJ.st. Dr1.111.l1g Superintendt'nt a 3/LS SIGNBD . ...' .D... - '1'ITLJD D "'~' .I) . !'.. i it 1 1 t~~ , , . (See Instructions and Spaces for Additional Data on Reverse Side) SE? 20 1968 DIVISION Of MINe .. .u..-. , S & MlNERAa.3 ~ "f\..I'IORAGe J ÎA.;1 D'.;.' k jU..' T .,~ INSTRUCTIONS G~neral: 'l'blH form IH ùcHig-TH>t\ for Huhmittln~ a complete and correct well completion report and log on all types of lands and leases to either 11 :¡"ederal agency or a State agency, or both, IlllrHllllllt to IIppli('nh\!' J"(~lcr¡1l lIud/or State laws and regulations. Any nete:-:lsary Hpecial instrudions concemlllg the U!H~ of thiH form anù the number of copies to be HllllllliUet!, )llIrt i('lllnrl)' with J"-'J-:'lIrd to lo('al, urca, or rt>g-()Tlul Jlroc{~dnr('s nn(1 pl':!eU('('s. eithpr are shown below or will he issued by, or may be obLaillcd froUl. the local Federal and/llr S(a!l~ IIfli<'e, SI'(' illstr\lI'lIoll~ 01\ items ~~ an(1 ~.1, awl 33, bl'hnv regarding' separa!!' r('ports fur separate compleliolls. - Ir not fill'd prior to 11)(' tillle this stlllllllill'y r('('I)I"d is S\lblllittetl, copies of all (,llrn'lltly IIvailable IfI;.';s (tlrill('rs, J!;cologists, sample and core analysis, 1111 types ('leetrie, ete.), forma- tion ant! prl'SSlln' tests, alld dif'<,('tillllal sun'CJ's, should tI(, attncllcd hereto, to tl\(~ ext(,lIf. n'(lI¡Ïl'eu by appJie-aIJIe--I,'ederal and/o!: State laws awl rl'g"Ulatiolls. All lltta('hments ~1}(JlIld 1)(' Ijslt,lI Oil tllis fll!'lll, S,oc' ¡(("II :~;;, ' Item 4: If I Ill''(' II'(' II/) applil'ahll' ~all' rL,([tlir('lIll'nts, locutions Oil Fe<l(\ral or Ilidian IlIml shotlld he des(~rihed in accordance with Federal rl'(luirelllents, Consult loeal Stat~ or 1"l'dl'l'al olli('(' [fir spl'('ifi(~ illst rllI'lÎIIII":, Item 18: IlIdj,'a(' wlli('h ,d('\'aljllll is tlsl'd as I'l'fererll'l' (wlll'n' Hut otll('rwise ¡.;lIo\V!l) for dl'ptll IIll'asufelllclIL" ~i\'e!l ill other spaces on this form and ill allY atta('hments, Items 22 and 2": If Ihis wl'll is ('01llf,]l'tl'<I fill' separate pfodtl<:tiou trow 11101'(' (hall 0111' intl'",'al Z,III(' (multiple COJ/Ipll'liun) , so state il] item ~~, and ill item 24 show the producing ilillon;,!, 01' ¡1I(PI'vaLy, to!'(S), IlOlt(IIIIIS) alld lJaIll<~(S) (if any) for oldy the illter\'al l'('porteÜ in item 33. ~uùlliit a separntè report (Jla~e) on tIIÌ,'j form, adequately identified, [III' ('adl additiollal jlll('n'a! to he separatl,ly prodtl('ed, showing' the additional data pertiIJent tu stich iuterval. , Item 29: "'<';(/I'!,,'< ('!'I/II'lIt": AUa('hed sllppl\'Jll!'ntal records for this well shollld show tile detail" (If any lIlultiple stag-e cf'lIJentiug and the lo('atioll of tlIe cementing tool. Item 33: SlIlJlllit a separate c()lIIp]ditl!1 /'f'¡HJrt (111 this [orIll fo/' eadl interval to he se!¡aratC'ly IJroduCL'll, tSee instruction for items 22 and 2-1 above.) ~' 37, St:~nIAnY OF POIWUS ZONI<~S: . SIIO\\ AI.I. IMI'U/tTA!oIT ZU:';f:S OF PO/tOSITY AND COSTE NT!> THEREOF; CORED TNTERVALS; AI'D ALL DRILL-STEM TESTS, tÞt:I'TII INTE/lVAI. T~;STBD. CUSIIION I:SEO, TJ.\!F: TOOL OI'BN. FLOWING AND SHCT-IN PR¡';SSl:RES, AND RECOVERIES D~;SCRIPTION, CONTENTS, ETC. " INCLUDING'! 38. I' I ¡ I I ¡i Ii I I Ii Ii Ii I: II GEOLOGIC MARKERS TOP DOTTO!lI , I I I Set Tester @ 9800' t..:/tail @ 9812 'HD I TLJp 61 1') it' T1.~'D (1' 49'L'it:" T'.,"):'P 1\1) [,,9211 ~l. --"-"~.L ~ -, ,,- - - , .. TSIP 12~q~ I~p (2) ¿()?~ rvp (?) 517P .... ... ..L ~~.., ~~ \ / J_","'~ - .... J I PcoTP QscP P¡iP ("')?J! H, I ;) ~ .L J .J,r, ..L'" ,) L -) - ,¡ . ! Recover e(~ 10 ,bbl ;-a t hole flu iè in I addition to \~Tilter ct.lshio:l. I I FOIl~IATION TOP , NAME' MEAS, DEPTH TRUE VERT. DEPTH DST I¡ 1 ~1iddle Kenai 9854' 9874' Top.D ~. 9350 8727 D-2 9505 8882 D-3 I 9830 9207 I 10023 9400 :3 I <: ~ I,. Oz I - < U ¡ roo"~, ¿: I ~' >õ:: ~< .~ ø ~ 'c< ~ J) « F cuiY. == p zo u~,o ;:~2 : ~ \>-'-"'-1,",',-'-'.','- , ~~-~' 0 '4; ¡JJ ~f) ~ f'~T ~ '='= ' > " Q I . "'--, \- " , '- .~ U,S. GOVERNMENT PRINTING OfFICE : 196~3e3ô 811.233 \ ,"-,. ,)" ! . "~K' " /r~,' ./ L-Ý '(, yl t 3 -- ~ .' SHEET A . PAGE NO.. UNIc..,I~ OIL CO. OF CALIFú. ~NIA DRILLING RECORD SPUD DATE 7/3/68 COMPo DATE 8/21/68 CONTRACTOR. Coastal DrillinR ' . RIG NO. TYPE UNIT- DRILL PIPE DESCRIPTION- 4-1/2" Grade E ELEYATIONS: VVATER DEPTH R:-r-.-Te-eeEAN-FL-00R KB to Ground 1evel-12 , R. T. TO MLL VV R. T. TO DRILL DECK - . R. T. TOPRODVÇ,fIO!'¡.J)ECK APPROVED: '~;,' .._~J~ 111,,/J LEASE KE~AI DEEP UNIT WELL NO.fJ2 FIELD Kenai Gas Field' LOCATION 337'S & 4274'E from NW corner Sec tion 7. T4N. R11W. SM ,.' . PERMIT NO.- 68-49 T.D. 10522 ' DEVIATION (B.H.L.) COMPANY ENGINEER SERIAL NO. Anc. 028142 T.V.D. -, .-. ", , I .:! './;'" , :j v M'UD.þEL. DEPTH & DEVIATION ! VERTICAL 0 ANN.. JET DIRECTIONAL f3 , c¡ .1990 377 4038 2048 5037 999 5694 657 6042 348 Drill 6045 2 6078 33 6484 406 6934 450 7318 384 ~~b í /Jj1- 7706 388 l/ If 8040 3~4 8371 331 8682 311 8916 234 9107 191 9270 163 - 9270 - - 9486 216 12-1/2 9610 124 9 9737 110 12-3 q 9912 175 10-3 ¿ 10035 123 9-1 4 10115 80 9-1 4 10208 93 12-1/2 10308 100 11~1/2 3-5810432 124 13-3/4 .. 10522 90 7-112 " 10522 I - J - aDen 110477 BIT RECORD JET TYPE SIZE ESC-l 3-1/2 BHDJ Ese-II 3-1/2 CoNV F.C\C'.-l OSC ESC-1 OSC OSC OSC SS-3 5S-3 HT3 BIT DEPTH NO. SIZE 53' 1 12-1/4" 321 2 " 971 1RBI " 1325 Ho1l1 17-1/2 1121\ 1RR 17-1 t.,. 1613 3' " 1990 4 " 4038 5 " 5037 6 " 5694 ì " 6042 8 8-5/8 6042 9 " 6045 10 " 6078 11 " 6484 12 " 6934 13 " 7318 14 " 7706 15 " 8040 16 " 8371 17 " 8682 18 " 8916 19 " 9107 20 9270 21 9270 22 9486 23 9601 24 9737 2) 9912 26 10035 27 10115 28 10208 29 10108 30 10432 31 10522 32 1.0477 33 MAKE CP Smith CP SID i t h CE- HTC CP HTC HTC HTC' Globe DATE 7/3/68 4 5 6 11 11 13 14 15 16 19 19 19 20 21 '21 22 23 23 24 25 26 27 30 31 ß1l.L68 .2.. ..2- ..1 !! 2 ..Q. ~ .~ -2. II Jet f 0 L....di :r e.c..tJ r. n Op~npn nnlp'- rio rpp '-' . 'j T)r; 11 ~h()p 'Pill' Fn1'" T) Lost 2 Jets . - - 1-1 /2 3-1/2 3-1/2 3-1/2 3-1/2 3-1/2 , . 1'-f{3:J.- ;. - ¡'Ii ,.J1-- a~ sho~. lost 3 cones Ran on iunk Ran on;unk " " " " 2. - "':;;. I - , > " " II " ., " " .. " " " " " ~ .3. ~ïlt .,~/.... . ~/., '" '/'" I 7J¿ 3-9/16 " " " " " " " .. " " Drilled retainer " " " " " " " " " " " " " " " ODG HTe " " " Globe HHT3 HTC XDV HTC' ODG " " " Contract T.D4 lO.40D' Cond. ê.nd 102 Clean out Clean out " " " " " " " " " .. 6" ow RcCC'Ff\j'CD ~ . \~~r' [ 'i 5EP V9 '~~lS . DIYISION Or MINe.. ¿, i\t\INL:RAL3 ANGiC)?.AGE ~ - , . ., t I --. - '- . . '~ UNIt..~ OIL CO. OF CALIFO. ..NIA MUD RECORD SHEET e' PAGE NO. 1 LEASE . KENAI DEEP UNIT TYPE Lignosu1fonate WELL NO. 2 FIELD KENAI ,GAS , DISTRIBUTOR Barqid J . I , DATE DEPTH WEIGHT VISCo W.L. PH SALT OIL SAND SOLIDS REMARKS 7/3/68 180' 72 65 8 - - - - - Spud. Mud 4 776 80 60 10 ' 5 1180 78 56 8 - - - 3 - 6 1325 80 75 8 Condition for 13-3/8" 8 1325 78 61 9..10 RiQ Renairs. run 13-31.8" 11 2950 78 44 10. 8.5 1200 8 3 13 12 3934 79 45 8.8 8.5 380 6 2 9 . , 13 4800 81 41 8.2 8.0 500 4 3 15 14 5888 79 45, 6.2 8.0 700 3 3 16 15 60{.2 80 40 5.8 8.5 900 3 2.5 15 Condition for logs 16 6042 80 40 5.8 8.5 900 3 2.0 15-' Condition for 9-5/8" 18 6022 78 46 6.0 12 600 Tr 1.5 13 Drill floats & cement 19 6077 75 '41 4.6 10.5 600 8 3/4 10 20 6655 77 40 4.8 10.0 600 8 1/2. 11 21 7109 79 42 4.6' 10.0 750 6 3/4 12 22 7622 80.5 40 4.8 9.5 800 6 3/4 13 23 8095 82 44 4.6 9.5 900 6 1/2 15 24 8431 83.5 41 4-8 9.1) 9'00 I) 1/4 15 25 8900 84.5 46 4.4 9.5 900 8 1 16 26 Q107 Q2 49 4.8 Q.O 500 5 1-1/: 20" Raised wt. due to well kick 27 Q1R7 q2 50 4-6 9 0 600 5 1-1/ 20 28 6000 92 47 4.8 9.0 600 5 1-1/ 20 Drilled bridQe Dlug. Raised wt. 29 6007 92 47 4.8 9.0 600 5 I-I/: 20 to control gas: 30 9270 97 52 Ú 8 9.0 600 5 1-1/ 23 31 9485 95 48 4.8 9.0 700 4 1-3/ 22 8/1/68 9650 94 53 4.4 9.0 750 8 1-3/ 22 ' 2 9793 94 ,6 4.6 9.0 800 8 2 22 1 1 n01R 91 " Ú. 1 9 0 ROO 6 2 22 ú. 10090 01 ,ú. ú. R 9 0 ROO 6 2 22 5 10200 91 52 4.6 9.0 800 - 6 2 23 6 101,2 94 ,6 ú. 7 q 0 71}0 6 1-1/ i 23 7 10:;11 9ú hO ¿ 4 <} 0 6,0 6 1-3/! 23 R 10C;?? Qh 61 4, C} 0 hOD S 2 23 10 10C;ï? Qh hO ú. b. C} 0 C:;l10 I} 2 23 11.- 1 i 10,11 QlJ. ,1 ú. h 9 0 ,,0 , 1-1/ 23 18-1c} QR,9 91 ,1 - R, ú,O - - - . . . . R r: {~ \l~EIVfD , S.EP lÐ 1:<AlS DIVISION - OJ- ;\-11/"1" .. " ANCH.-'~;: ~~ iVlINëRAl'" 'J. GE v . " ~ '-- I i I I . . UNIb-r~ OIL CO. OF CALIFO'c~¡~IA WELL RECORD SHEET C PAGE NO. - 1 . LEASE KENAI DEEP UNIT WELL NO.2 FIELD KENAI GAS WEIGHT THREAD GRADE DEPTH 58' 1317 ' 6026' 10522' - 9859' REMARKS- Conductor driven 38' below G.L. See Drilling History for Detail "" " I I I 1 t CASING & TUBING RECORD SIZE 20" 13;...3/8'! 9-5/8'1 7" 3-1/2' 54.50 4011 29U' 9.2 SIC Seal LOC~ Buttress Buttress J-55 N-80 N-80 N-80 liner - TIW hngr @ 5821' - See Detail For packer and sleeve detail - see History rrf:.ATE I N - 1". H V Al F.Tn- T'I ..,. " C! 1"\ 'JI]' T CON - IN .3/68 10092-10080 Gas Produc tÜ n Open 10036-10028 " " 9910-9884 " " 9588-9558 " " - 9522-9510 " ,. 1/12/68 9812-9800 OST #1 ODen but non productive .' PERFORA TING RECORD I I I 1 I I I I I j j J DATE INTERV AL NET OIL CUT GRAV. C.P. T.P. CHOKE MCF GOR -.' ~ARKS 9/10/6) Shut n{Ternp) . . - - - INITIAL PRODUCTION WELL HEAD ASSEMBLY TYPE: RECEIVED 5EP 19 ,~6g CASING HEAD: i - I Shaffer KO 13-3/8" slip on weld 900 X 12"' .- CASING HANGER: . - Shaffer ,13-3/8" x 9-5/ß_,,~5J.._im; w/secondary seal CASING SPOOL: DIVIS/OI~ at M//'U::_-, LX MINERALS ANOiORÞ.GE TUBING HEAD: Shaffer 12" . 900 x 10".L 1500 series (500011) w/2-2" Cameron 5000 psi va1ves ¡ TUBING HANGER: Shaffer 10-3/A" 00 x.3-1/2" buttress w/primarv and secondarv sea¡ MASTER VALVES: Cameron s"ing1e unit tree. 10"-1500 series. 5000/1 CameronL_swab and master w/wing valve (5000 U) TUBING HEAD TOP~ CHRISTMAS TREE TOP CONN.: 3-1/2" 8rd 1 I -.---.- - LEASE '-' "~ UNION OIL CO. OF CALIFORNIA DRILLING RECORD .SHEET D PAGE NO.1 KENAI DEEP UNIT KENAI GAS FIELD WELL NO. . 2 FIELD. DATE E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS 8: RESULTS 7/3/68 " 4 .7/5/68 7/9/68 10 11-15 7/16/68 "1325' SPUDDED @ 1:45 PN 7/3/68. Drilled and surveyed 12-1/4" hole to 321'. Jetted, drilled and surveye~ to 971'. Dynadri11ed to 981', dynadri11 malfunctioned. . Drilled to 1325'. . Opened 12-1/4" hole to 17-1/2" hole from 53' to Ì324'. While POH draw~orks broke down (6:00 A}1 7/5/68). Repaired dra~~orks, operable at 02~0 hI's 7/8/68. POH, checked tools, conditioned for casing and rab 32 hts 13-3/811 casing. 13-3/811 CASING DETAIL Baker Flexiflow shoe 13-3/8",54.5/1, J-55, STC csg. Baker Flexiflow Collar 13-3/8", 54. 511, J-5~, STC csg. " Landing Joint below KB 32 Jts 2.10 40.58 1.65 1260.90 11.77 1317.00 1317.00-1314.90 1314.90-1274.32 1274.32-1272.67 1272.67- 11.77 11.77- 00.00 1 Jt 31 Jts Centralizers as follows: two on shoe joint, one each on top of next four joints. Halliburton cemented w/450 sx class "G" cement w/50% Perlite and 6% gel followed by 200 sx class "G" w/3% CaC12' full returns throughout job, 50 sx cmt to surface. Bumped top of plug w/l000 psi @ 1300 hI's. wac. 1325 Cut off casing, welded McEvoy "csg. head, did not hold"cut off. on 13-3/8" stub, welded on Shaffer casing head. Tested to 300011 Installed 12" 5900 BOE, tested blind and pipe rams to l5001f - OK. failed, installed new hydri11, tested to 1500 psi - OK. Drilled collar @ 6:00 PM. Welded - OK. Hydrill float 6042 Drilled 12-1/4" directional hole to 6042'. Conditioned hole, m~de water trip, returned to bottom and conditioned hole and mud. 6042 Rigged up Schlumberger and ran DIL and BSG logs. Conditioned hole, made wiper trip and POH. Ran 147 Jts 9-5/8" 40ti N-80 seal lock casing. 9-5[8" CASING DETAIL HOWCO float shoe 2:05 6026.99-6024.94 9-5/BII, 4011, N-80 seal lock csg. 1 Jt 39.70 6024.94-5985.24 Hewco float collar 1.75 5985.24-5944.75 Howco self fill collar 1 Jt 2.10 5944.75-5942.65 Ho~co Landing Collar 0.80 5942.65-5941.85 9-5/8", 4011, N-80, Seal lock csg. 99 Jts 4024.21 "5941.85-1917.64 Howco DV collar 2.10 1917.64-1915.54 9-5/8",4011, N-BO,Seal lock csg. 46 Jts 1902.54 1915.54- 13.00 Landed below KB 13.00 13.00- 00.00 147 Jts. . 6026.99 Installed centralizers at 6020',6010',5880',5107', 4824', 4620~J 4457',1958',1900',1880',1230',1190'. Cement baskets @ 1925' and 1935'. ' RECEIVED .5EP "<g f :cA{S OWIS/Ot-¡ 0, ";INr.:, " MINERAL:) ANCH,G,'<AGE LEASE '-' "-' UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET 0 PAGE NO.2 WELL NO. 2 KENAI GAS FIELD KENAI DEEP UNIT FIELD DATE E.T.D. DETAILS OF OPERATIONS. DESCRIPTIONS 8c RESULTS 7/1'1/68 7/18/68 7/19/68 26 7/27/68 7/31/68 8/7/68 8/8/68 8/10/68 6042 6042' 9107 9270 10522 TD 10522 10522 Howeo cemented thru shoe w/500 sx 1;1 Perlite w/6% gel followed by 200 sx neat cement, thru DV @ 1916' w/300 sx 1:1 Perlite w/6% gel. Full circulation during both jobs. ~ad slight cement returns when broke circulation thru DV, had approximately 100 sx cement returns on second stage indicating probable channeling. Set slips in KD head, cut off casing, installed tbg. head and tested to 3000 psi~ Installed 10" 51500 BOE, tested blind rams to 2000 psi. Rt, drilled DV collar, tested pipe rams and Hydrill to 2000 psi. Drilled floats and shoe, lost 3 cones. Ran short tooth bit, drilled on junk. Ran Globe junk basket and recovered small amount of junk. Drilled ahead. Drilled 8-5/8" hole to 9097'. Encountered drilling break from 9082' , to 9097'.0 \'¡ell kicked. Increased mud weight from 85/1 cu ft to 9fJ! cu ft. Killed well. Drilled to 9107'. Drilled to 9270'. Made up retrievable bridge plug. RIH to set plug' @ 5900' in order to inspect BOE following well kick. Unable to set. Found BP had unlatched from setting tool, fished for BP. Ran Hawco E.Z. drill cement retainer and set @ 5906'. Removed BOE and checked for sand cutting. Checked head, changed Hydrill,rubber. Installed hydrill, tested to l500U, unsatisfactory. Changed Hydrill, tested - OK. Drilled 8-5/8" hole to 10400' contract depth. to 10522'TD. conditioned hole for logs. Drilled ( on day rate) Ran Schlumberger DIL, Sonic, FDC, 5NP, HRD and 18 shot side~a11 gun. Cleaned out and circulated between every second run. conditioned hole for liner. ' Ran and landed 7" , 2911, N-80 liner as follows: 7" LINER DETAIL p Baker "G" Shoe 7", 291), N-80 Butt. Csg. Baker "G" CollaL' TIW Landing Collar 7", 29/i"N-80 Butt. Csg. XO - Buttress X 8rd TIW Hanger w/sea1 2.30 42.35 1.80 0.92 4628.99 0.90 23.50 4700.ï6 10522.00-10519.70 10519.70-10477.35 10477.35-10475.55 10475.55-10474.63 10474.63-'5845.65 5845.65- 5844.75 5844.75- 5821.25 1 Jt 111 Jts 112 Jts , Cemtd liner w/lOOO sx 11611 slurry class "G" crnt mixed w/ fresh wtr. . Pre-' ce~ded cement w/200 cu ft fresh water. Displaced cmt w/2lS bblß- 94/1 cu ft mud. Bumped plug w/300Ò#. Pressure bled off to 1500#." Floats held OK I - when pressure was bled off. No cement returns during job. Oveidisplacing by 12 bbls. Set TIW liner hanger pack off. Pulled cups out of hanger and tirculated. CIP 2:00 PM B/10/68. (5000# required--to break circulation prior to cement1ng, assumed-to be due to plugging of float equipment). Ran 6" bit and scraper to 10477', circulated clean. . RECE!VED 5 EP\ <9 , ~~œ DIV/SION Of ;\'II/'H:~, & M/NëRAL3 ANChORAGE . '- '---- UNION OIL CO. OF CALIFORNIA DRILLING RECORD LEASE KENAI DEEP UNIT DETAILS OF OPERATIONS, DESCRIPTIONS ~ RESULTS 'WELL NO._2 FIELD. KENAI GAS FIELD DATE E.T. D. , SHEET D PAGE NO. 3 8/12/68 ETD 10477 8/14/68 ETl> 10477 Perforated from 9854 to 9874' W/4" carrier guns w/4HPF~ Ran HOWeO tester with tail @ 9812' and packer @ 9800'. 'Tested as follows: OS! Ill: . Opened tester @ 11:15 AM wit~ very weak blow. Closed tester for ISIP @ 12:05 PM. " Openea tester for flow period 1:35 PM. ,No blow when opened, no blow to very light blow during flow period.' Closed for final shut in @ 4:00 PM Inside Recorder Outside Recorder IHP 6193 6132 IFP (1) 495 492 FFP (1) 519 492 ISIP 1235 1229 IFP (2) 519 492 FFP (2) 544 517 FSIP 990 985 FliP 6144 6132 Recovered 10 bbls rat hole fluid. Found sample in tester to be mud. Pulled and laid down tester. Rigged up Schlumberger and perforated the following intervals: 10092-10080'; 10036-10028'; 9910-9884'; 9588-9558'; 9S22-95l0'. Cleaned out w/bit and scraper to 10477'. Installed 3-1/2" pipe rams. as follows: Ran 3-1/2" J N-80 J 9. 80t; buttress tubing 3-1[2" TUBING DETAIL Guiberson Shear Nipple X-Over. 8rdo X Buttress 3-1/2" Buttress Tbg. Otis X Nipple, X-Over Buttress X 8rd Guiberson RH-l Packer X~Over 8rd X Buttress 3-1/2" Buttress Tbg. Otis x-a Sleeve Valve 3-1/2" Buttress 'Tubing //1 Blast Joint 1l2 Blast Joint 3-1/2" Buttress Tubing //3 Blast Joint 04 Blast Joint 3-1/2" 'Buttress "Tubing Otis x-a Sleeve Valve 3~1/21f Buttress Tubing X-Over Buttress X 8rd Guiberson RH-l Packer X-Over 8rd X Buttress Buttress Tubing 3-1/2" Otis X-) Sleeve Valve 3~1/2" Buttress'Tubing But~ress Pup Joint Shaffer Tubing Hanger Landed below Kelly Bushing 0.80 0.71 29.87 1.10 1.00 6.55 0.82 31.45 3.75 187.55 20.26 19.76 31.68 19.74 19.75 32.31 3.75 30.71 1.00 6.55" 0.82 31.05 3.75 9352.42 8.00 1.25 12.00 9859.00 1 Jt 1 Jt 6 Jts 1 Jt 1 Jt 1 Jt I oj I i 1 Jt 300 Jts 312 Jts " I 9859.00-9858.20 9858.20-9857.49 9857.49-9827.62 9827.62-9825.92 9825.92-9824.92 9824.92-9818.37 9818.37-9817.55 9817.55-9786.10 9786.55-9782.35 9782.35-9594.80 9594.80-9574.54 9574.54-9554.78 9554.78-9523.10 9523.10-9503.36 9503.36-9483.61 9483.61-9451.30 9451.30-9447.55 9447.55-9416.84 9416.84-9415.84 9415.84-9409..29 9409.29-9408.47 .9408.47-9377.42 9377.42-9373.67 9373.67- 21.25. 21.25- 13.25 13.25- 12.00 12.00- 00.00 f) f- r" "~ ! \! r- n ;:z ¡"~. ,., ~ ~, *~ t ; - ". '~ ' . ." ..- 5 E.P "' <9 í ~~(ß DiVIS/Of'! Or ¡vil!;r:., ~< 1\t\INEìV\L3 ANCi-i'=)~U\GE LEASE l' .; i ¡, ! ;; t --' , -; -- "--~ UNION OIL C~. OF CALIFORNIA- - ,- DRILLING RECORD - SHEET- D PAGE NO. t. WELL NO. 2 FIELD. KEr;AI GAS FIELD KENAI DEEP UNIT DATE 8/14/68 15 16 18 19 20 -~-- --- -"--" E.T.D. 10477 10477 Tbg 9859 I - DETAILS OF OPERATIONS, DESCRIPTIONS Be RESULTS Displaced drilling mud with water - set packers. - - Tested packers and opened sleeves @ 9782',9447' and 9373'. Rocked well with g~s and blew well until clean. Surface pressure 3800 psi. Closed sleeves and set X plug in sleeve @ 9373'; sleeve leaking or not closed. Differential press~re stuck plug in sleeve. In an attempt to equalize pressure, wire line tools were blo~~ up hole and stuck @-appróximately 8660'. Dropped tool to cut off piano wire prior to fishing for tools. Cutter malfunctioned and fell to the side of the original plug running tool. Rigged down wire line service. RU BOE and 151 lubricator w/Hydrill on top of stack. Equalized pressure above and below donut. Tested BOE to 4000#. Unseated packers and circulated water followed by 930 mud to kill well. Pulled tbg, well flo~ed after pulling 18 stands. Circ. bottoms up. Pulled tubing and recovered wire line fish. Reran tubing. Continued running tubing, landed with tail @ ~859' (no change in origiQal tubing detail). , Removed BOPE. Installed Cameron Xmas tree, tested tree to 50GOn for 15 mins. Displaced mud with fresh water. Set bottom packer, tested to 20000 for 10 mills. Set top packer. Opened sleeve bet~cen packers and tested top packer to 2000# for 10 mins. Openad well to atmospher~, would not flow. Opened sleeve above top packer, opened annulus and depressed water down tubing and up casing with gas. Closed top sleeve. Ble\\: well clean.' Closed sleeve between packers. Set "Q" plug in nipple @ 9825'. Bled annulus to 0# psi. 'Closed all valves on well head and tree. Annulus was filled with water above top packer.and well shut in. RELEASED RIG @ 9:00 A}1 8/21/68 ReCEIVED sr::p -J <9 1~'!)6g ViVISIOI\ Or ¡\'Í/I'-':.:'. , A'II"'!>. ~ .. '.-- v 'Y """I\j,L,;¡ ANCH(')'~AGl: 4 .. ,.' i- , ~-, i~; F; ".., ~, [:' "" r-; - ~--- ~-- E t;; ~¡ 1': i':; i:i -Ii 101 Ii'-. ~: Ii ii ~, ~: ~: ,,¡ £ ,",' r: ¡; ¡: E~ 1: [ f ( ;c: ~ i !- ~, ¡ I J ~ I ¡ I r J f ~ e. ; f ~ ~ ~ i ( I J ~ ¡; ;;¡ -~ - --- --. . --- -fT"'."-¥:- { ~ _. 5. AþI NL;.'LERlCAL CODE ¡:,tJ, 'i /,~ ;/ Form No. P-4 REV. 9-30-67 STATE OF AlASKA S'UBMIT IN DEPLICATE OIL AND GAS CONSERVATION COMMITIEE MONTHLY REPORT OF DRilLING AND WORK OVER OPE.RA TIONS 6. LE..<\SE DES:GXATIOX AXD SERIAL NO. 1. Anchorage 028142 7. IF I:'\DL\;":¡. .\LOTTEE or-. TRIBE XA:\IE OIL n GAB Cl WELL L.....J WELL ~ 2. NAME OF OPERATOR Union Oil Company of California 3. ADDRESS OF OPERA TOR OTHER 8. L'"XIT,FAR'1 OR LEASE :'-:.-\..'IE Kenai Unit 9. WELL :!\:O 507 W. Northern Lights Blvd., Anchorage, Alaska 4. LOCATION OF WELL 99503 Kenai Dee Unit #2 21-8) 10. FIELD A:.'<D POOL. OR WILDCAT 337'S & 4274'E from NW corner Sec. 7, T4N, R11W, SM F 11. SEC., T.. R. M.. (BOITO;\1 HOLE OBJECTIVE) Section 8 12. PERMIT NO. R1lW, SM 68-49 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE. CASING AND CEMENTING .TOBS INCL'UDING DEPTH SET AND VOLUMES USED. PERFORATIONS. TESTS AND RESULTS. FISHING JOBS. JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOl$ CONDITIONS. KENAI DEEP UNIT #2 (21-8). AUGUST 1968 Drilled 8-5/8: directional hole to 10,522'TD. .. Ran Sch1umberger DIL, Sonic, gNP, FDC, HRD logs and sidewall sa~p1e gun. Ran 112 Jts 7" 29# N-80 Buttress casing. Hung with shoe @ 10522', float collar and top of TIW liner hanger @ 5821'. Cemented w/lOOO sx neat cement. Ran bit to 10477'ETD. Ran CBL and Gamma Ray-Correlation logs. Schlumberger perforated 4-1/2" holes per foot 9854-9874' for DST #1. rat hole fluid (mud) - no gas to surface. Schlumberger perforated 4-1/2" HPF in 7" casing: 10092-10080'; 10036-10028'; 9910-9884'; 9588-9558'; 9522-9510'. Ran 312 Jts 3-1/2" tubing with dual 7" packers. Hung w/tail @ 9859' and packers @ 9818' and 9409'. Installed Xmas tree, changed over from mud to water, set packers. Opened sleeve between packers and above top pkr. Pressured with gas down annulus. Displaced water out of tubing, blew annulus and tubing dry, 3000# surface shut in pressure. Closed all sleeves, attempted to set "X" plug in sleeve @ 9373' - did not set, blew 1000' up tubing string parting wireline. Fished for wireline and plug without success. Removed Xmas tree, installed BOE, pulled packers loose under pressure, circulated and killed well. Pulled tubing and recovered fish. Reran tubing. Set bottom packer @ 9818', top packer @ 9409', tail @ 9859'. OK. Brought well in flowing through tubing, surface shut in pressure 3800#. Cleaned up both upper and lower zones. Installed "Q" plug in tubing tail @ 9825'. Closed sleeve between packers. Bled tubing pressure to zero. Shut well in. Filled annulus above top packer with water. @ 10474' and scraper Recovered 10 bbls Tested pkrs - RIG RELEASED 8/21/68 - 9:00 AM. " i\ 0:: r: "": .: . ' ,,'.,.", :-'" SIGNED j'):V¡SICht 0;: :/I¡:-".-:.~~o;-'\i,¡\,,:[:(,\\..::;, t,.¡,-:(¡-~C:,~:I~.GE: !-t. I hereby certify is true and correct TITLE Dist. Drl~. Suptd. DA'l'J£ 9/10/68 NOTE-Report on thi form is required for each calendar month, regardless of the status of operations, and must be filed in duplicatt with the Division of Mine & Minerals by the 15th of the succeeding mo nth, unless otherwise directed. t ,,( Union vii Company ~ .1Iifornia Qiý 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 ,,«. Telephone (907) 277-1401 D(ü/ u1 ; OJ] ffiJ' Ï'¡ ..,..::-;~ ~Iì "'U',", U!"~,)(/,i:)IIIIJU' , o:'.c:.I LJ ° September 9, 1968 Mr. T.R. Marshall, Jr. Petroleum Supervisor Division of Mines & Minerals 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Marshall: We are returning to you P-7 forms on 2 and Trading Bay Unit State G-9. We regret that these forms are incomplete but at present the necessary data is not available as both wells are temporarily shut in. Ken' °t #2 will not be produced until all drilling is completed in the Gas Field. ~S should be in the fairly near future and at that time we will notify you and the form can be returned to us for completion. It may be a matter of months before TBllS G-9 will be worked on further. We will also notify you at that time. We thought it preferable to send you a somewhat incomplete form rather than wait for an indefinite period after completion of drilling before trans- mitting any completion information. /bg Very truly yours, ¡J f /1&) B.E. Talley i 1 District Drilling , I .I Superintendent '\IC\} (t\\J\, R t, (\ \'6\:,'¿ S ~_\ '\ of \\'ltRA\.5 \,:5 ß.. N"- Or N\\\"I" Gt:. DN\5\O~ þ..~C'c"\O~ I Z I 0'" ',' .1 . ~ , ; I. ; , ,,' .". ,~ , Form P-,,7 " ;j SUBMtT'IN DUPT,IC.i .. /' J"'1. -::.,-, , STATE OF ALASKA;, , \ OIL AND GAS CONSERVATION coMMitTEE' (Sp{' oth~', Ill' ~t ruct ion~ on 5, API NUMEliÏC"AL"ê;õDi re\'er~e side I ." 50-133-20121 WELL COMPLETION OR RECOMPLETION REPO~T AND LOG * '~~=~,~~~~,- ' 6, LFASE DESIGN A'nON ANT) SERIAl.. NO. 1a. TYPE OF WELL: 011. 0 WELL (;AS I'Vl WELL ~ DRY 0 ,. Anchorage 028142 7, IF INDIAN, ALLOTTEE OR TIUBE NAME Other b. TYPE OF COMPLETION: NEW ill WOn!- 0 WELL -e:..J OYER 2, NAME OF OPERATOR ". ," DEEP- 0 EN PLL'(; 0 DACK DIFF, 0 r.ESVR, Other' 8. UNIT,FARM OR LEASE NAME: Kenai Unit Union Oil Company of California 3. ADDRESS OF OPERATOR 507 W. Northern Lights Blvd., Anchorage, Àlaska99503 4. LOCATION OF WELL (Report location clearly and in accordance with an¡¡ S,tate requirements)- At surface 337' S & 4274' E from NW corner Sec t.ian:..~ 7 ,,!:4N, R11W, SM At top prod. tnterva1~rep':}ted below 1Ó2,' S' and 2556,' ~ o(,;~surface:~Location , , - 1\' .. ( ,~ .s 1...G.,-,S G; " ^ ê 1.:6 Ç) ~...... , 2' f ~í'.;.il Attot:ì,~Pth ' W~.f and ~~~~..~Of, Sur ace ::ócatt~~ 1 v'"\ vJ'"' t,,",hß)-'" , 4~(1 ~~¡,< ~"\"~ :: ~$'¡)' \:~ .<, "" ~u(; ;;:P/ ..' ,,~. 13. DATE SPUDDED 14. DATE T.D. REACHED 15. DATE COM? SUSP OR ABAND. "', . 9. WELL NO. Kenai Deep Unit #2 (21-8) 10. FIELD AND POOL, OR WILDCAT Kenai Gas Field 11. SEC., 1'., R., M., (BOTTOM HOLE OBJECTIVE) Section 8, T4N, RIIW, SM 12. PERMIT NO. 68-49 . '~6. EL~rATIONS (DF,~, RT, GR, ETC)"P7. ELEV. CASINGHEAD 8/21/68 ; w 92 ! 80 MD & TVD 20. IF MULTJPLE êOMPL.,':! 21. INTERVALS DRILLED BY HOW MANY*" , , ROTARY TOOLS O-TD CABLE TOOLS 10522 - 9896 10477MD & 9851 'VD ¡". "7 .1..' - 22. PRODUCING INTERVAL(S) , OF THIS COMPLETION-TOP, BOTTOM, Ni\IWE (M~ ANÐ:iTVD). 23. WAS DIRECTIONAL , SURVEY MADE MD10092-10080 -VD9469-9457 /MD10036-10028-VD9ft13-9'405}MD9910-9884-VD982 7- 7/3/68 8/7/68 18. TOII'AL DEPTH, MD & TVD 9. PLUG, BACK 926¡/MD9588-9 558-VD8965-8935/MD9522-9 510-VD8899-888 7.; 24. TYPE ELECTRIC AND OTHER LOGS RUN, . ',,' Yes ~L. Sonic 9 FDC 9 SNP. HRq - Sidewall samples ~' 25. CASING RECORD (Report all strings: 'set in wim :,:¡; ~2 ,', ,,' CASING SIZE WEIGHT, LB/FT. GRADE DEPTH SET, (MD) Hbu.1 S):ZE , CEl\iLNT'INGRECORD AMOUNT PULLED .. 13-3/8" 54. 5iJ J-55 1317 11-1l~" '" 650 sx "G" w/Per1ite ,,' .." 9-518" 4011 N-80 6027 1:2-1/4" ',:1000 sx "G" w/Per1ite ~ :.') . 26. LINER RECORD " 27. TUBING REDORD SIZE TOP (MD) BOTTOM (lVID) SACKS CEMENT" .,SCHEEN' (MD) SIZE DEPTH SET (MD) PACKER SET (MD) "" 7" 5821 10522 1000 'Gun ,'perfs 3-1/2" 70J7 ~HS24 , 9415 ' 28. PERFORA'fIONS OPEN TO PRODUCTION (Interval, siz.e and number) 20. ,. ACID, SHOT, FaAC'T'URE" CElVŒNT SQUEEZE, ETC. 10092-10080 DmPT~H INTERVAL (MD) AlVIOUN'r AND KIND OF MAT'ERIALUSED ' 10036-10028 4-1/2" HPF 9910-9884 - 9588-9558 -,- ',.. """ 9522-9510 , , ' 30. DATE FIRST PRODUCTION PRODUCTION 1 " , '.. PRODUCTION METHOD (E'lowing, g:lS lift, pumping-size and type of pump) DATE OF TEST. HOURS TEs.'l'ED CHOKE SIZE GA,S-M;CF. I WELL S'I'ATUS (Producing or :>hut-in) Testing W A'I'ER-BBL. GAS-OIL l::¡.ATIO I - ,'--,' PROD'N FOR OIlr--oBBL. TES'rPERJIOD I )1- FLOW. TUBING CASING PRESSURE CALCULATED OIlr--oBBL. PREss. 21-HOUR RATE ;1 .. I 31. DISPOSITION OF GAS (Sold, used for uel, vented, etc.) GAS-MC'!!". WATER--BBL. OIL GRAVITY. API (C'QRR.) ",I: : ,) .. 1 ,..- TEST WITNESSED BY ".,i 32. LIST OF ATTACHMENTS SIGNED DATE 9/3/68 3, " hereby certify t *( ee Instructions and Spaces for Additional Data on Reverse Side) ~ "-..,J LJ.t.....{ ~ -.""" í...t.J ~~} ~ et:' CÇ, r ", """- ~,- ;;:,:, 'I-- '--.:..~ t-,l ..:.,,-) z' 0 cì) s: Q INSTRUCTIONS ."", ".. , ~ ",., :.-! '"- ...' """ ", . , ,",- '0 ---General: This form is designed for submItting-~ comRI.et~ and correct well c9m?let:¡oF:!: r~port and log on .;-=all types of lands and leases 'in Alaska.:: .'.' /' ,.,,- " ~ " 0") ,-.I :;;; , "i Z ~ O(~' !J..' C;; C') <1' ',I) 0-' 2: r - '-, ,',S; J: '. U '-. .2 O<r , . " >-', ;"" " , " , ' " , , -' '" , ' -... ':Item:: 16: Indicate which elevation is ,Ùs~d as.~'reference (where not otherwise' sl:ioWn)}p~ depth measure- :, ment~ given in ether spaces on this for.mand in-~,any attachments. . " ""¡ , ,'- -, :,Itein$ 20,~and 22:: If this well is comptet~d fo~:'separatc production from more than one interval zone (multiple-, completion), so state in itern:.20, and. in item .-,22 show the prc.:Jucing interval, or intervals, -:':top(~j, bottom(s)ä'nd name :(~) (if any) "f~r:~nly: the ini~~vál reported in item 30. Submit a separate report -(page) on, this förm, adequ'â1ely '¡~entifred. for::each additional intel val to be seperately produced, show- ,~ing 'the:~dditíonðl data pertinent'~to s~ch',intêrÝ:al. ' , , " " '", " " Item26: "Sac:.ks Cement": Attached supplø,me~t~1 recordsJor this well,.'~hould sh~yv the details of any mul- :-tipl~~ stage cèmenting and the loê'ation~:'bf"the cementit,g' tool. ' '", , .,. ',: " .'. '_: ~~_. ¡ ", :Jtem~28: ~SubÌ11it~a separate compJetiorr~ rèport.~9n thi~ form for each interval to be separately produced. ,~-(See instrt,/cti!9n f~r items ~~t anQ.~'22 ~þQ!e).:; ., ,,', "ì ,"" '" ':- :': ,,; ", ,,-- ".:, CI ,- . " ,"' '"-';""" " ' 34. SUMMARY OF FORMATJON T-ES'l'S¡jNÇ~:UDIN(1 INTERVAL.TESTED, P~(JRE DATA AND .a.EC.OVERIES OF OIL:~GAS. '.., ~': ;, ;,:,..:"" ,', '<, ,," ,," , ~'., WATER AND'MÛb .. ,,~": .;-', ,"'\ "1", DST III : Perforated W/4," gùn~~,w/~llPF w/tai1 @ 9812 'MD - 9187 fjVDi: .;:~ ~:'~ IHP 6132#, IFP (1) 492# ,::,FF~, ell) 4,92#, FSIP 98511 ,FHP 6132#. ,',. ',.. Recovered 10 bbls rat h~~e ~luid (mud) n" " ~ì "'"" { c"..¡ from 9874-9854". ¿'~Set :tesiter @ 980p'MD " i :~~ ',.:' :,/ ,,-: ""', ISIP 122911;! IFP (2) 4rn:11:',:: FFP (2) ~17#, ..-.:¡, ~....' ", .' ,,: ... in addition} to water cushion. ; ,:' " " , r',..,: " ".. ,-. , .. I..,,: n'1 ",.. ", .' ...,' .- . .. ""', ',:';/ , c-: , - ,'~ ,eO, .., , , t': " ' ":1 '""" ~ , M, CORE DATA, A1YrAClf(:::-aRlEF~DESCRïpIT¡T.ONS OF LITHOLOQ)", POROSITY. FRACTUR1!;S.~:ÃPPA.RENT DIPS: :"~ ,:; >AND DETEÇ1.'ED SHOWS OF chi. GAS- OR WATER,':, '",', 1:~) C;' ".. ":: C' .. .., ,-..' I.,. , '", None . , ..1 . , (: ~.., ", .. . . '",'. '.", ,,-, <:' , C..': ,,' ~"""I -., I,...: :..", . .., '., .,,': ..", " ,6 ':" .,'0, ,,','::" "" '.,,' ,.:(~' 'i ",' " " ~ ',' , ,.,,', ¡ ":1, " .,.': r," ..c' ",'" c. "".., " .....,' .",,' ., ,,"', ",' ..",; ,.." ," , ' ,.,. " , . " " ,,/ 35, GEOLOGIC' MARKERS NAME MEAS. DEPTH Top D D-2 D-3 D-4 9350 9505 9830 10023 ',"", "" ,... ..,j ',': ,~ '- {;) ..J ~- ~ tJ...¡ z: ~ ""-'\\"; L-....r .' .J L.1".,¿ --~, ,-'.~ "', ," , '- "",---,;~:-::: -> (::.~: . ~ !.i..! C ""':. J) <l ...~"..," ,. '-'-' Q: iil ",' ~b ~; C -- / ." ?: :r - L' ~,-,~~/., ~U ù. 2 '-'-1 'Q <{ lJ.;,.,¡ Ck~' '..,'--:'" ,z 'R 1.1) ~ a . 8727 88S,2 92Q7 94Q.P ¡:" "", ..., ;, '" :- ""', ",. ,", ", ,-., ,!.." ...""" '"',,, (}Nt i: if , / Form No. P-4 STATE OF ALASKA SUBMIT L'" DEPLICATE r. REV. ~-30-6'i 5, API NC\1ERICAL CODE OIL AND GAS CONSERVATION COMMITTEE 50-133-20121 6, LE.<\SE DES:GXA'IIO=,," AXD SERIAL NO, - MONTHL Y REPORT OF DRilLING AND WORKOVER OPE.RA TIONS Anchorage 028142 1. 'i. IF II"DiAX. ALO, TEE OR TRIBE XA:\IE OIL :x GAB ~ WELL WELL U OTHER 2. NAME OF OPERATOR 8. 1;;-';-IT,FAR.\I OR LEASE XA,;..1E Union Oil Company of California Kenai Unit 3. ADDRESS OF OPERATOR 9, 'WELL!'O 507 w. Northern Lights Blvd., Anchorage, Alaska 99504 Kenai Deep Unit /12 (21-8) 4, LOCATION OF WELL 10. FIELD A-""D POOL. OR WILDCAT Kenai Gas Field 337'S & 4274'E from NW corner Section 7, T4N, RllW, SM 11, SEC.. '1'.. R.. M., (BOTTOM HOLE 0 BJ'ECTIVE) Sec. 8, T4N, RllW, SM 12. PERMIT NO. 68-49 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE. CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED. PERFORATIONS. TESTS AND RESULTS. FISHING JOBS. JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. KENAI DEEP UNIT #2 JULY 1968 SPUDDED 1:45 PM 7/3/68 Drilled 12-1/4" directional hole to 1325' Opened hole to 17-1/2" to 1325'. Ran 32 Jts 54.511 J-55 STC casing. - 13-3/8" Hung with shoe @ 1317', flexif1ow collar @ 1276' Cemented w/450 sx class "G" w/50% Perlite and 6% gel, followed by 200 sx class "G" w/3% CaC12. Drilled to 6042'. Ran Schlumberger DIL and BSG logs. Ran 148 Jts 9-5/8" 40/1 N~80 Seal Lock casing Hung with shoe @ 6027' and DV @ 1918'. Cemented thru shoe w/500 sx 1:1 Perlite w/6% gel followed w/200 sx neat cement. Cemented thru DV @ 1918' w/300 sx 1:1 Perlite w/6% gel. Drilled 8-5/8" hole to 9270'. '. Now Drilling REC,EiVED ¡~UG 121!i3F\8 DIVISION OF MINES &, MiNERALS ANCHORAGE NOTE-Report on this orm is required for each calendar month, regardless of the status of operations, and must be filed in duplicatr: with the Division of Mines Minerals by the 15th of the succeeding mo nth, unless otherwise directed. . s true and correct H. I hereby certify t SIGNED TIT&ist. Drilling Superintende»,t.~ 8/5/68 ~ ~ , ~;' l UNITED STATES / l DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Form app~oved. ~ ~udget Bureau No. 42-R356.5. (- LAND OFFICE ----r---- ----O-?, -CJj-7.-"--_u_--- önc. _0 .'-T¿ LEASE NUMBER -Kë-¡:ÙiT-lfÙTC---_n_-- Pþ UNIT --- n- ------- _n___- - - -. - - __n______---- --- LESSEE'S MONTI-It)T REPORT OF OPERATIONS .', State ____AIJ~,_SK!j.____--_nm_n__- County nnK[Xc\lnBQE~OllGIL_--- Field uu___KE:\Al__GAS__EIELD..- - - --- -- -- ---__m______--- The follo7.oing is a correct report of operations and production (inclnding drilling and prod7.wing wells) for the m,onth of n___mn___~~~!)~---------___--_nm_, 19n~~1 -_m_.nmmm-___mm--_--mnm_n-__mnmnm_-_mm_nnn Agent's address .c u~_?_?___\~~~ml~?E~_~~:_~~~m~~~~f:~:~~---~~~~~_._-,-- - --- C07n pany - __~~1:I?_r:- ~~}-- _~_?~~E~:E:Y.__~tmg~_~J.:_f_<.:~~'.n i ~ A. "'1- "'. ~'" .l~'" 00-0'- . ~l/I/ )<. ¡dill' ,~ ::~~~:_~~!-_~':t2:~_'_n~~__~~-~_t::.?:_n_!.?_~- _~~_~_m__nmm__'__n______- ---- nn__mn_- S~gned --- -- -/,-1/---- -IJjh¡L,'(___mm_--____-O?,_£E.u.:I'-r'J_i, 1 c. y ? ,. I v (I' v¡.. t,., 'Í" Phone -----~:_~'!..~'!~ ~ ~ L- n_m __mmnm_n 00 -- __n__mm _n n 00 nu n - - ------ - A g en t' s ti tl e nl~J:~~_._-Ji_t:iJJJ~ !lKn$_~11)_~}~'j-~t_~S_1..~-ç _r~ n t ------------- ---:==-~-==--=:-' GALLONS OF -, ßARREL;r~F =- - -- - R£MARKS--- -= SEC. A:'-D Twp R'NGE W};LL DAYS BARRELS O)' OIL OHAVITY Cu. FT. OF GAS OASOLl~E ,v ATER (If (If drilling. d()pth; if sbut down, ~lIu'e; 7i OF ~ .... No.' PHO!)UC~;D (In thousands) RECOYEIŒD none so state) date :Ll1d re"ult of test for ¡MolIne , , . content of ¡m:s) --------- - --~----,----- ,------ KEt\AI'):ŒP L;::-d'; [f2 -"-"-'-"--'-" "'--'--'-"'------ '-'-- SPlUDED 1:/15 PH 7 !3/6B Dc;.. "lc:d12..,.1/!yl! d X(:~ctJ(!né11 hole to 1.325' Opeìl(!d ¡ole to 17..1/2!1 to 1.25'. Ko.n 32 ,,1.:5 1. -.3/8 I, 51; .5f}, '-'.55, SIC c;)sing Hun;'. ,,;'ith sh')c G) ..:JI/t, fle;, if 10';" collar @ ,276'. CI;'.,\q~'.~'P" <.,,'";t"¡ !',,')() ,~y l"'l;'l')"'-,' I (:," C",,':\(>;-¡t p;,t11 ,n,C~1 P',:ll-'} 'r t.c, 'O:>,!""I(1,' t~ 'I ""c-1' ......t.,.>,,;..., -"..._.'"~,_. ..' ""~"""."",.-",/,, ",.,-.",-..",..,'-./,.;::,".." [013 o1,.,:ed b;? 2.1)0 sx clo.s~ "e" ce:i1e:.nt .,.,d.t: 1 3;;: CaC} ') c. D:::L led to (: )(~2' . Ran Sc.h:it1\ì'.be '~f',~(~r ')IL and BS lo(1~' v ..' t_,~' " Itan l./¡SJts ).-5/8! t~O!; r;...BO SCtd. Lock cas in). , :'1'1,'1'1", ~')1""1 "1',','1'-' I] "('\')'¡'~',"",(l J~'T (¡J lr)}H' ~",(,....',1 vI,-,..\::, ,.I... "'.B ,'\:: -,"-0 C\~m:"nte(; thr 1 ,.81!(;¡:, \'7/500 s:{ 1:1 P¡O.rJite ,.,7it1l 6X gel fol1o\}c~d ~-l1200 s:.: neat c.wt. CQElfnteçì thLl DV () 1918' \07/:00 sx 1:1 Perli:e \dth C~ gel. Dri.: led ,~3~.5/ V' ho"c to 9:~70 . ~;roY"' <11- l' 1 11' T" 0 ";,, , ,.... ~ , ""'6 REC,EI ED ro, iJ r~ -\' ') q f) ~ "'\~'_"'_f.J"."- DIVISI 'N OF NIl Nt ~ & MINERALS ÂNCHOR .GE ------, ,no . no NO'1'E.-There wer-e ----____---_m___n____mn__,-_m-- runs or sales of 011; m_m-----n____u_----_u--u___m_____mM cu. ft. òf gas sold; --_-m______m__m____-__----___mm--n runs or sales of gasoline during the month. (Write "no" where a.pplicable.) . NOTE.-Rcport on this form is required for each calendar month, regardless of the statu,> of operations, and must be filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervi:-sor. Form 9.329 (January 1!J50) U.S. GOVERNMENT PRINTING OFFICE: 1964-0-729-784 Form P-3 REV. 9-31>-67 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate i,"V,," J þ'/ 5. API NUMERICAL CODE OIL AND GAS CONSERVATION COMMITTEE 50-133-20121 6. LEASE DESIGNATION AND SERIAL NO. SUNDRY NOTIC'ES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a diffierent reservoir, Anchorage 028142 Use "APPLICATION FOR PERlVIIT-" for such proposals.) 1. 7. IF INDIAN, ALLOTTEE OR TRIBE NAi\1E OIL D GAS ~ WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT,FARM OR LEASE NAME Union Oil Company of California Kenai Unit 3. ADDRESS OF OPERATOR 9. WELL NO. 507 w. Northern Lights Boulevard, Anchorage, Alaska Kenai Deep Unit #2 (21-8) 4. LOCATION OF WELL 10. FIELD AND POOL, OR WILDCAT At surface Kenai Gas Field 337'S & 4274'E from NW corner Section 7, T4N, RllW, 11. SEC., T., R., M., (BOTTOM HOLE SM OBJECTIVE) Sec. 8. T4N. R11W, SM 13. ELEVATIONS (Show whether DF RT, GR, etc. 12. PERMIT NO. STATE OF ALASKA " <: ". \ "'" r..:Z:) .',- RT 1~ 1 I I 68-49 Check Appropriate Box To lindi'c,ate Nlat'ure of Noti'ce, Relport, olrO'therDlata 14. NOTICID OF INTIDNTION TO : SHOOT OR ACIDIZE MULTIPLE COMPLETE ABANDON. SUBSEQUENT REPORT O~: WATER SHUT-OFF § FRACTURE TREATMENT SHOOTING OR ACIDIZING REPAIRING WELL TEST WATER SHUT-OFF PULL OR ALTER CASI~G FRACTVBE TREAT ALTERING CASING ABANDONMEN'T. REPAIR WIDLL CHANGE PLA!'JS (Other) i S f L ti (NOTE: Report results of multiple completion on Well (Other) Chan~e n ur ace oca on Completion or Recompletion Report and Log form.) 15. Dr:SCRIBE PROPOSED OR CO~!pr,ETED OPERATIO:SS (Clearly state all pertinent detall¡.¡, and r;lve pertinent dates, Including eøtlmated dat~ of starting an~' proposed work. RE(.'E!VED ,\-. . I ' ï h -- 1C1C8 J 1...1 \"" () ,:J n DiVISION OF MINES & MINERALS ANCHORAGE II true and correct Dist. Drilling Superintendent TITLE DATE 7/3/68 APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE P. ~ DATmY~ rr' See 'I!nstrucfions On Reverse S,ide ( ,.f '1\ June 3~ 1968 b: Kenai Ð.,Ualt f2 (21--8) Union Oil eo.,GYo f California t Operator .Hr. Ioher:'t T. AM.Jr'an District 'LaIv1.Iia88&- untO,D, 011 ~.,ol~Cali£.J:a1. 280$ iCe_l't ,fteM.C; Aac.,.se. Aluka U503 Deu:S1r: I_to_. P .1.....ftaj.tbo., X:M8. ,ap,l,icat 'to af orperød;, t te'ctll 't,n rata...... 811,. Well ,...,II1.tI ...co~e,ch:ip.ue &:&Ot,xeqsú.4.. Ve.Q'ítl"iu,lJ .~.. ~.. I.... .¡are'bal!" ,31:. Peh'olewabpeni.aør ~'~:..' j.,. .4\."""',.' , M 1M,10...., ': I. . , ~::' MEMORANDUM State of Alaska ÐUI8108 OF MI" I .&øD M1JØJ~t$ TO: I J" 18 A. Villt-.- Dtnetor DATE : able 3, 1'" FRO M: !lløøu &. ""'11. k. hUe t. lJII Supe:nUoc SUBJECT: 1'-"*1 1M., Vatt 12(21-8) Ølat-. Oil eo.p~ of Cal1fonau, 0,. a tor lacl"".. tile "'1:.." applicatJea for pend.t to ckillt locattoD plat. ad . check ia .. IT T .4at of $50.00 ferftlia& I_A UH:j8 he 1 MtØ."e F', r" I [ I 25 ,C !,o MEMORANDUM State of Alaska Dm&1OII or MlIU ØD MDÆ' ALl TO: I DeJa L ..... ~ 181 "'-' 188pIIC t« ...'_. ef ,... DATE : ~ 3" 1168 FROM: 'lM811 a. """11. Jro Pemt 1- Sup8ÞùoI' SUBJECT: 1it_1 Døp Grd~ 12 (21-8) 1JIdøa 011 Calif., of CalUonta. ÐpW -- 18c1o... 18 . oop" of die IØNWIIIl ...lic8dea te *111 for tile aMve e....1~ ..11. tIIh ja he 1Þ8tan , F', Fonn P-l REV. 9-30-67 SUBMIT IN TRIP4 (Other instructions reverse side;' 5T ATE OF ALASKA OIL AND GAS CONSERVATION .cOMMITTEE' APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK DRILL [] DEEPEN D PLUG BACK D OCJ la. TYPE OF WORK b. TYPE OF WIILL OIL D GAS WELL WELL 2. NAME OF OPERATOR OTHER RINGLE ~ ZONE lÃJ Ml"LTIPLE 0 ZONE Union Oil Company of California 3. ADDRESS CII5' OPERATOR 2805 Denali Street, Anchorage, Alaska 99503 4. LOCATION OF WELL At surface Approx. 405' S & 4381' E from NW corner, Sec. 7, T4N, RIIW, S.M: (Drilling Island #1) At proposed prod. zone Top "0" Interval 405' S & 1950' E from NW corner Sec. 8, T4N, RI1W, S.M. 13, DISTANCE IN MILES AND DIRECT,ON F3.0M NEAREST TOWN ORPOST OFFICE. 7 miles from Kenai 14. BOND INFO~ATION: . Pacific StatewIde UnIted TYPE Surety and/or No. 15. DISTANCE FROM PROPOSED. LOCATION TO NEAREST PROPERTY OR L~~ASE LINE, FT. (Also to nearest drig, unit, if any) , 18, DISTANCE FROM PROPOSED LOCATION. TO NEAREST WELL D:3.ILLING, COMPLETED, OR APPLIED FOR, FT. Insurance Company B-55372 16. NO. OF ACRES IN LEASE 3350' 2560 19. PROPOSED DEPTH 4100' 10,386'MD,9850'VD 21. ELEVATIONS (Show whether DF, RT, GR, etc.) RT 90' 23. PROPOSED CASING AND CEMENTING PROGRAM I) (,.~J../ rE ",,' , API 50-133-20121 5. 6. LEASE DESIGNATION AND SERIAL NO. Anchorage 028142 17. IF INDIAN, ALLOTI'EE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME . Kenai Unit 9. WELL NO. Kenai Deep Unit #2 (21-8) 10. FIELD AND POOL, OR WILDCAT Kenai Gas Field 11. SEC., 1'., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 8, T4N, RIIW, S.M. 12. $100,000.00 Amount 17. NO. ACRES'ASSIGNED TO THiS WELL '? 640 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX, DATE WORK WILL START" June 15, 1968 SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH QUANTITY OF CEMEN'r 17~" 13-3/8" 54.5# J-55 1200' 1200 sacks ¡,,~;/> ,) 1 Fd lu ~') , -- It"~,! " I,,' , '-' 12!z¡:" 9-5/8" 40# N-80 6500' 2000 " ":?i",Ö'/¡' i',,/'!"'(, ¡"~II , 'I" 8-5/8" 7" 26# N-80 10400' 800 " /,,'») , (' 1/') /) / ¡"., /.) I ! Cement 13-3/8" casing in 17~" hole at 1200'. Install 3000# BOPE~Drill 12!z¡:" directional hole to 6500'. Run electric logs. Cement 9-5/8" casing. Install 5000# BOPE. Drill 8-5/8" directional hole to 10,400'. Run electric logs. Cement 7" Liner 6400' - 10,400'. Complete for production. ' Bottom Hole Location: Approximately 405'S & 1950'E of NW corner Sec. 8, T4N, RIIW, S.M. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen or plug bac,k, give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen directjonally. give pertinent data on subsurface Locations and measured and true vertLcal depths. Give blowout preventer program. ~' ~ ~. I he,-reb: Certi.f~' tha. ~ t~ ..,' , . SIGN ' ~ ,'/ I ' (This space for State office use) DATE May 21, 1968 OF APPROVAL, IF ANY: TITLE District Land Manage! SAMPLES AND CORE CHIPS R.EQUIRED OTHEH REQUIREMENTS: 0 YES ø NO I DIRECTIONAL SURVEY REQUIRED A.P.I. NUMERICAL CODE ~ YES 0 NO ÇO '" I 3 3. ,- 2. 0 I ~ I PERMIT N APPROVAL DATE, ,.Tl1np 1 ~ 1 qh~ THOMAS R. MARSHAll, JR, TITLE. ËxP.Ctl'iiv/"> ~A"'!'r"¡'nry *See Instructions On .Rewle:rsé:>Si4eGas Conservat ionCömm itt-ee t/ 3 / ~ £r' APPROVED B PATE ;- -----..,' .-- ------..:1----------.-- ------." ._--------,,- ----,.-'-- "-'----'---_., --- -..--.- ---. --..-" -. --'.'--"--- 33-30 jf- t I + I I I I I T -¡ I oj 3? 3 3-32 ~-----. -'------. ~ -) I_) -.::>p 34-31 ~"... . :. " ------ '~-~+-.,., --r" ----I. --L .,~ 21 -6 ! ' ?t'! , II -6 ,: I -'-""""""""".""'" ".. . J $ I I .*4 3 t 6 I Q 43 -16 A I I I I T 5N- RIIW T- -:;:- ~::R ~w_1 I I I I I I i I I"" P .."..."".....- ....."...--."..... ...."... - .'. 33-1 ~- ..0 'j A!, K_D.UI : ' , ~ , . ~ / I j / +'4=6!f:'~ 21 - , "* 14-4 I -II) , 0 I I ~ I I ....1 , . L TARGET B oÓ TA~GET A "'" 0.. .- -- i- -, ~ -- - - - ..:0 \- 1950 -..I I K.D 2 PROÞ. B. H. LOC- TMQ 10,500' Tvd 9850' I I I 01 L COMPANY OF CALIFORN IA ALASKA DISTRICT + UNION + 43 -7 WELL LOCATION PLAT KEN AI DEEP UNIT No.2 + (21 - 8 ) I DATE: APRIL,1968. 0 2000' I I SCALE ¡I" = 2000' ~ I I I ¡ f (" . ~ c:-::J ,n, ¡;:, ~, ' <Ii-;=¡ ~~U' ,",,\ II" '," , ",,',:;' ......\ : '",: I'~ ~ [;;1 ~ ~a, @w ~~~$~fÆ KEITH H. MILLER, Governor . ~.;~~~D.\~~..".r~;=~NT @EF NJ.~TU;ll~.1l. I!~lE§OQJQt~1ES ùIVIS ION OF OIL AND GAS C-- -~_. '~" :=) 3001 PORCUPINE DRIVE - ANCHORAGE 99504 li. :¿. Talley l;nion Oil Company 9u9 W. 9th Ave. Anchorage, Alaska Reo Kenai Unit #21-5 0 (formerly Kenai Deep Unit #3) and Kenai Deep Unit #2 (21-8)1 99501 Gentlemen: The below-indicated reports and other information on subject well, as required by AS 31.05.030 and the applicable Oil and Gas Conservation Regulations, are: ŒJ OVERDUE. Please submit. [J INCOMPLETE. We are enclosing. Please complete and return. APPARENTLY IN ERROR. ,-,- " We are enclosing. Please correct and return. --, W REQUIRED REPORTS AND OTHER INFORMATION .,~..... ~ Directional Survey [] Electric or Radioactivity L~g. 0 Sepia 0 Blue line [J Mud or Lithology Log. 0 Sepia .0 Blue line [J ,'-I) Application for Permit to Drill or Deepen. [J P-3, Sundry Notices and Reports. ~ P-4) Monthly Report of Drilling and Workover Operations. CJ P-7, Well completion or Recompletion Report. [] Samples and Core Chips t .,,' [J P-l3, Report of Injection Project. [J Chronological Well History Remarks: Please send us two copies of each well's deviation survey. Very truly yours, ~~~ Homer L. Burrell Director "'\