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Home My WebLink About195-019 STATE OF ALASKA RECEIVED AL(A OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS MAR 14 2018 1.Operations Abandon Li Plug Perforations U Fracture Stimulate[ Pull Tubing LI cy asU Performed: Suspend ❑ Perforate ❑ Other Stimulates Alter Casing IDChange pproved rPnril ❑ Plug for Redrill ❑ 3rforate New Pool ❑ Repair Well❑ Re-enter Susp Well❑ Other: Water Shut Off D 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska LLC Development Q Exploratory ❑ 195-019 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic Service ❑ 6.API Number: AK 99503 50-029-21780-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0047503 DUCK IS UNIT SDI 3-09A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A ENDICOTT/ENDICOTT OIL 11.Present Well Condition Summary: Total Depth measured 14,700 feet Plugs measured 14,018 feet true vertical 10,289 feet Junk measured N/A feet Effective Depth measured 14,018 feet Packer measured 8,179&12,319 feet true vertical 9,891 feet true vertical 6,831 &8,988 feet Casing Length Size MD TVD Burst Collapse Conductor 161' 30" 161' 161' N/A N/A Surface 2,512' 13-3/8" 2,512' 2,512' 5,020psi 2,260psi Intermediate 10,519' 9-5/8" 10,519' 7,942' 6,870psi 4,760psi Production 4,449' 7" 12,638' 9,153' 7,240psi 5,410psi Liner 2,173' 5" 14,650' 10,256' 10,140psi 10,500psi Perforation depth Measured depth See Schematic feet OW True Vertical depth See Schematic feet SC '. Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/13 CR/NSCT 12,406' 9,032' 9-5/8"x 7"Tie Back 1,504 MD Packers and SSSV(type,measured and true vertical depth) 7"x 4.5"SAB-3 4.5"HXO SVLN See Above 1,504 TVD 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: 132 0 10,318 1,900 362 Subsequent to operation: 158 0 6,031 1,600 341 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q 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: 317-594 Authorized Name: Bo York Contact Name: Taylor WellmanlV Authorized Title: Operations Manager Contact Email: twellman G(G7hiIcorp.com Authorized Signature91------- Date 3/13/2018 Contact Phone: 777-8449 gL1 Form 10-404 Revised 4/2017 r BDMS J_ MAR 2 2 20bmit Original Only • Duck Island Unit Well: END 3-09A , '14 0 SCHEMATIC Last Completed: 4/27/1995 PTD: 195-019 Hileora Alaska,LLC WELLHEAD OPEN HOLE/CEMENT DETAIL SAFETY NOTE: KB Elev.:79.4'/ GL Elev.:±14.5' McEvoy 13-3/8" 3,254 cu/ft Permafrost in 17.5"Hole H2S Reading Average 230-260 9-5/8" 1,150 cu/ft Class`G'in a 12-1/4"Hole PPM on A/L&Gas Injectors. 30 f.• 7" 112 cu/ft Class"G"in 8-1/2"Hole Well Requires a SSSV.Chrome 5" 1,095 cu/ft Class"G"in 8-1/2"Hole Tbg/Liner&Jewelry 1 CASING DETAIL 13.3/8 Size Type Wt/Grade/Conn DriftID Top Btm 30" Conductor N/A/N/A/N/A N/A Surface 161' 13 3/8" Surface 68/L 80/Btrs 12.415 Surface 2,512' 2 9-5/8" Intermediate 47/NT8Os/NSCC 8.681 Surface 10,519' -_ 7" Production 26/L-80/LTC-Mod 6.276 8,179' 12,638' 5" Liner 18/L-80/LT&C 4.276 12,477' 14,650' TUBING DETAIL 4-1/2" Tubing 12.6/13 CR/NSCT 3.958 Surface 12,406' ,_ 3 WELL INCLINATION DETAIL Max Hole Angle=64 deg.@ 8,200' Angle at Top Perf=59 Deg.@ 13,971' 4 JEWELRY DETAIL No Depth Item 5 4, 1 1,504' 4.5"HXOSVLN,I0=3.813" GLM DETAIL:HES 4-1/2'x 1.5"SPM 9cr , 1; 2 3,574' STA 5:VIv=Dome,Latch=RM,Port=16,TVD= 3,574',5/31/2016 y; 6 3 4,492' STA 4:VIv=Dome,Latch=RM,Port=16,WD= 4,479',5/31/2016 4 5,734' STA 3:VIv=S/O,Latch=RM,Port=24,TVD= 5,509',5/31/2016 5 7,441' STA 2:VIv=Dmy,Latch=RA,Port=n/a,TVD= 6,472',4/27/1995 6 8,145' STA 1:VIv=Dmy,Latch=RA,Port=n/a,TVD= 6,808',4/27/1995 9 5/8 a l 7 8,179' TIW 9-5/8"x 7"Tie Back Packer r 8 12,307' HES X Landing Nipple,10=3.813" 4 9 12,319' 7"x 4.5"Baker SAB-3 Packer M B 10 12,382' HES X Landing Nipple,10=3.813" MN ID 3.725" 9 11 12,393' HES XN Landing Nipple,I0=3.725" [12373'ELM 1/16/18] @12,393'- ; R 10 12 12,404' WLEG-Bottom @ 12,406' [12384'ELM 1/16/18] XN Nipple_�4 m. 13 12,460' 5"JM Liner Top Packer „ 11 „. 14 12,477' 5"HMC Liner Hanger 12 15 14,025' Baker Inflatable Cement Retainer 7 =' 13 16 14,228' Baker S-3 IBP-Set 1/2/1997 14 A PERFORATION DETAIL P' Sands MD TVD FT Status Shot Sqz Size SPF ' 13,970'-13,990' 9,866'-9,876' 20 Squeezed 1/24/98 5/2/98 2-7/8" 4 4ir 13,974'-13,994' 9,868'-9,878' 20 Open 8/15/98 - 2-7/8" 4 TOC @ 14 018 ' 0 Y 14,002'-14,032' 9,882'-9,898' 30 Squeezed 4/24/98 5/2/98 2-7/8" 4 ELMD 14,004'-14,025' 9,884'-9,895' 46 Open 5/13/98 2-7/8" 6 14,025'-14,050' 9,895'-9,908' 46 Squeezed 5/13/98 Future 2-7/8" 6 Top ' ' of Baker � ` 1 14,034'-14,054' 9,899'-9,910' 20 Squeezed 3/2/98 5/2/98 2-7/8" 6 ICR @ 14,025' ` , z •_+: - fiT V 14,062'-14,082' 9,914'-9,925' 20 Squeezed 5/13/98 Future 2-7/8" 6 14,070'-14,100' 9,918'-9,934' 30 Squeezed 4/24/98 5/2/98 2-7/8" 4 fi 16 K2B 14,138'-14,150' 9,955'-9,961' 12 Squeezed 5/8/97 5/2/98 3-3/8" 4 14,166'-14,178' 9,970'-9,977' 12 Squeezed 5/8/97 5/2/98 3-3/8" 4 14,192'-14,204' 9,984'-9,991' 12 Squeezed 1/10/97 5/2/98 3-3/8" 4 14,210'-14,214' 9,994'-9,996' 4 Squeezed 4/22/95 5/2/98 2-1/2" 4 14,210'-14,214' 9,994'-9,996' 4 Squeezed 1/10/97 5/2/98 2-1/2" 4 14,220'-14,258' 9,999'-10,020' 38 Squeezed 2/17/96 5/2/98 3-3/8" 6 14,254'-14,258' 10,018'-10,020' 4 Squeezed 4/23/95 5/2/98 3-3/8" 4 I. 14,266'-14,292' 10,025'-10,039' 26 Squeezed 2/17/96 5/2/98 3-3/8" 6 14,308'-14,312' 10,048'-10,050' 4 Squeezed 4/21/95 5/2/98 3-3/8" 4 5".4f' ,_ `' 14,360'-14,364' 10,078'-10,080' 4 Squeezed 4/18/95 4/19/95 3-3/8" 4 TD 14,700'(MD)/TD=10,280'(WD) 14,488'-14,492' 10,129'-10,156' 4 Squeezed 4/19/95 4/19/95 3-3/8" 4 PBTD=14,541'(MD)/PBTD=10,189(WD) K2A 14,481'-14,490' 10,149'-10,155' 9 Squeezed 10/17/95 10/17/95 3-3/8" 6 Reference Log:SBT on 4/13/1995 GENERAL WELL INFO Revised By:TDF 3/13/2018 API:50-029-21780-01-00 Sidetracked-4/27/1995 1 1 • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 3-09A Slickline 50-029-21780-01-00 195-019 1/5/18 2/23/18 Daily Operations: 1/3/2018-Wednesday No activity to report. 1/4/2018-Thursday No activity to report. 1/5/2018- Friday PT PCE 250psi LOW/2,000psi HIGH. PULL 4-1/2" BBE *ser#HBB4-26* FROM HXO NIPPLE AT 1,470' SLM (1,504' MD) DRIFT AND TAG IBP AT 14,210' SLM W/3.62" BARBELL ASSEMBLY sat down at 9,190' slm picked up clean never sat back down. WELL LEFT SHUT IN UPON DEPARTURE NOTIFED DSO. 1/6/2018-Saturday No activity to report. 1/7/2018-Sunday _ No activity to report. 1/8/2018- Monday No activity to report. 1/9/2018-Tuesday No activity to report. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 3-09A CTU 50-029-21780-01-00 195-019 1/5/18 2/22/18 Daily Operations: 1/10/2018-Wednesday No activity to report. 1/11/2018-Thursday No activity to report. 1/12/2018- Friday CTU crew on site. PJSM. Prepare for BOP test. Fluid pack coil with 60/40 m. Well flowing. BOP Test to 250/3,200psi. Record on AOGCC 10-424. Pad Op shut in well. Install fusible cap, MU BHA#1-2.125" OD dimple CTC, 2.125" OD MHA (DBPV, disconnect(11/16" ball), 2.375" OD carrier, 2.125" OD DH filter,XO, 1.5" OD Abrado jetting nozzle. OAL= 17.29' (PDS logging tools consist of Battery housing/Temp/GR/CCL.) CCL is 10.95'from EOP and 6.34'from bottom of BHA. Pull tested CTC to 30k. PT tools to 4,150psi. Stab on well. PT to 310psi/4,000psi. Open well -T/I/0=1,880/1,879/95psi. RIH with BHA#1-Choke closed. At 2600' RIH,start pumping at .6 bpm SLK 1%down coil. Wt CK-6,500' = 18k, 12,000' =33k. At 12,400' RIH,start taking returns to tanks. Wt Ck at 13,900' =37k. Gas cap on well slowly bleeding down. Make 2 D/U passes with Abrado nozzle jetting scale at 2 bpm w/SLK 1%/running speed of 10 fpm. Tagged each down pass at 14,251' ctmd with 3k down wt. Minimal returns at less than 30%. FP coil. FP surface lines. FP well with 8 bbls 60/40. RIH and Dry tag IBP at 14,251' ctmd with 3k down weight. PU get weight back at 14,245' ctmd. Log up with GR/CCL to 13,874.8' ctmd. Stop. Flag pipe. Log up to 13,700' ctmd. Pause,then POOH. At surface. Close SV, BD, and PO well. L/D tools. Night cap BOPE to secure well. Remove fusible cap. Download and recover good data from GR/CCL. Make+4' correction to put CTM on depth.Tied into Atlas Segmented Bond log dated 6-May-95.TOP of IBP at 14,249' MD. MU cementing BHA for tomorrow. Set injector back. SDFN. 1/13/2018-Saturday Arrive on site. PJSM. PU injector. MU BHA#2- 2.125" OD dimple CTC, Wt bar, Wt bar,X0, 2.65" OD Pig Shear cementing nozzle. OAL=9.53'. Stab on well. Fluid pack and PT low and high. Leak on high PT at 1502 union. Change out gasket. Good PT to 300psi/4,000psi. Displace 60/40 in coil with 1% KCL out to meth tanker for re-use. Open well. T/I/O= 181psi/ 1,671psi/412psi. RIH with BHA#2. Cementers on location. MIRU same. Start well kill with 1% KCL down backside and coil at 6,100'while RIH -5 bpm/343psi WHP/580psi CTP. Pumped 275 bbls. Post well kill- FP coil on surface. Pump 65 bbls diesel down backside only at 2 bpm /275psi WHP. Hold PJSM with all. Static well conditions prior to starting job-233psi WHP/49psi CTP. Stop RIH at flag/correct depth. RIH Tag, PU,Wt back at 14,253' ctmd. Park coil. Pump down coil-choke closed -path clear. Mix cement at 12:10. 5 bbls FW ahead - PT cmt hardline. Load foam pig/Pump 4.5 bbls 15.8 ppg cement/Load tail pig with 7/8" steel ball 5 bbls FW behind. Displace to nozzle with 60/40 taking returns/200psi WHP/ 1,350psi CTP/ 1.5 bpm. Reduce to lbpm at 30 bbls away 485psi CTP/ 152psi WH. Ball on seat at 36.8 bbls pumped behind ball (coil volume =41.8 bbls). 1,557psi CTP. Holding solid. PUH slowly out of cement, bleed WHP to maintain 150-200psi. At 13,930'while PUH, ball seat sheared.At 13,700', pump remaining coil volume of 60/40. Cementers wash up and released. POOH.Tag up at surface. Close SV, BD, and PO well. L/D tools. 7/8" steel ball recovered from pig shear nozzle seat. Foam pig sticking out of bottom of nozzle. RDMO. Fusible cap removed. SSV closed. Final T/I/O when well SI was 234psi/ 1,602psi/282psi. 1/14/2018 Sunday No activity to report. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 3-09A CTU 50-029-21780-01-00 195-019 1/5/18 2/22/18 Daily Operations:'hill T � � � 111111 Bhp 1/15/2018- Monday No activity to report. 1/16/2018-Tuesday ***WELL SHUT-IN ON ARRIVAL*** (gr-ccl/set sssv). PT PCE 25014-LOW/2,400#-HIGH. RAN PDS MEMORY GR/CCL CORRELATION AND TAGGED CEMENT @ 13,920' CORRECTED DEPTH. (Tied into Atlas Segmented Bond log dated 06-May- 1995'). DRIFT TBG W/2.50" CENT. &S. BAILER TO TOP OF CEMENT AT 13,910' SLM (hard tag- no sample recovered). LAY EQUIP DOWN FOR NIGHT& PUT WELL ONLINE. • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 3-09A CTU 50-029-21780-01-00 195-0191/5/18 2/22/18 Daily Opet 1/17/2018-Wednesday PT PCE 250psi LOW/3,000psi HIGH. MADE ONE ATTEMPT TO SET 4-1/2" BBE *SER# HNBB-34* IN HXO NIPPLE AT 1,470' SLM (1,504' MD). PULL 4-1/2" BBE FROM HXO NIPPLE AT 1,470' SLM (1,504' MD). 1/18/2018-Thursday PT PCE 250psi LOW/3,000psi HIGH. MADE ONE ATTEMPT TO SET 4-1/2" BBE *SER# HNBB-34* IN HXO NIPPLE AT 1,470' SLM (1,504' MD). 1/19/2018- Friday PT PCE 250psi LOW/3,000psi HIGH. SET 4-1/2" BBE *SER# HNBB-34* IN HXO NIPPLE AT 1,470' SLM (1,504' MD) 1/20/2018-Saturday No activity to report. 1/21/2018-Sunday No activity to report. 1/22/2018- Monday No activity to report. 1/23/2018-Tuesday No activity to report. 4110• • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 3-09A CTU 50-029-21780-01-00 195-019 1/5/18 2/22/18 Daily Operations: 1/31/2018-Wednesday No activity to report. 2/1/2018 -Thursday No activity to report. 2/2/2018-Friday No activity to report. 2/3/2018 -Saturday WELL FLOWING ON ARRIVAL (pull sssv). PT PCE 250#-LOW/2,200#-HIGH. PULLED INTACT 4-1/2" BBE SSSV(HNBB-34) FROM HXO SVLN AT 1,470' SLM (1,504' MD). WELL FLOWING ON DEPARTURE, DSO NOTIFIED. 2/4/2018-Sunday No activity to report. 2/5/2018 - Monday No activity to report. 2/6/2018-Tuesday SLB CTU #6 arrive at Endicott. Check in at front Security desk. Well Flowing. MIRU CTU. Perform full BOP test to 250 psi/ 3,200 psi. Record BOP test on AOGCC form 10-424. NU BOPE on tree. Install night cap. MU BHA#1- Baker under-reaming assy. Set injector down. SDFN. • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 3-09A Slickline 50-029-21780-01-00 195-019 1/5/18 2/22/18 Daily Operations _ ��' 11 = = �� '��'�� 2/7/2018 Wednesday CT crew on site. PJSM. Pad Op shut in well. Install fusible cap. Stab on well with injector, 29' of lubricator, and BHA#1-2" OD dimple CTC, 2.13" OD DBPV,Jars, Disconnect (5/8" ball), Circ sub (1/2" ball), Motor, 2.63" OD DB Underreamer-dressed with blades to open to 4.191" OD. OAL=22.75'. PT to 250psi low/3400psi high. Open well to 800psi/1,800psi/370psi - T/I/O RIH with BHA#1. Wt cks=5,000'/13.5k. 10,000'/24.3k. Once in liner, displace meth out of coil with SLK 1% KCL. Dry tag at 14,040' ctmd down/Wt back at 14,029' ctmd. Mech counter shows 15' shallower. PUH to 13,682' Underream down from 13,682' ctmd. 1.5 bpm/ 1400psi CTP. Saw cement stringers at 13,990' and found hard cement at 14,137' ctmd. Underream hard cement down to 14,140' ctmd. Pump 10 bbl Gel sweep, open circ sub, and POOH chasing returns. FP coil and top 500' of well. Secure well. MU CT tools for GR/CCL logging run tomorrow. SDFN No Night Activity. 2/8/2018-Thursday MU BHA#2-2" OD dimple CTC, 2.13" OD DBPV, Hyd Disconnect (5/8" ball), 3.62" OD rotating centralizer(for retainer drift), XO's to 3/4" SR, PDS centralized mem, batt, GR, CCL. OAL= 13.87'. Install fusible cap. On well PT low 250psi/High 3,400psi. Open well to 448psi/1,500psi/370psi-T/I/O. RIH with PDS memory GR/CCL logging tools.TAG at 14,154'down wt/ 14,148' up weight (ctmd). Log up to 13,700' ctmd,flag pipe at 14,100' and 13,850'. POOH. Download good data,tie into Atlas Seg. BL dated 5/6/1995. Make+15' depth shift. Actual tag TOC depth is 14,148'+ 15' = 14,163'corrected depth. MU and PT CT tools to be used tomorrow except the inflatable retainer. SDFN Haul 1 load of SLK 1%w/NXS to put into UR. No CT night activity. • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 3-09A Slickline 50-029-21780-01-00 195-019 1/5/18 2/22/18 Daily Operations: 2/9/2018- Friday CT crew on site. Baker on site. PJSM. High OAP alarm during night. OAP 750psi. Start bleed to flowline. MU etainer.On Well. Install fusible cap. PT low 300psi/high 3500psi Open well-T/I/O= 679/1470/750. RIH with BHA#3 -2" OD dimple connector, 2" OD straight bar, Hyd Disconnect (5/8" ball), 2.09" OD XO, 2.15" OD Spotting valve, 3.38" OD inflatable cement retainer. OAL=21.35' Distance from EOP to COE = 17.85'.At 6,300'while RIH, bleed gas cap from tubing to tanks. Pump SLK 1%down backside, after 28 bbls pumped injection rate=2.3 bpm at 1260psi WHP. Maintain min rate while RIH. Discontinue bleeding OA. OAP= 2,98psi. Wt CK at 10,000' = 20k/RIH = 12k.Stop at upper flag (13,850'ctmd). EOP at flag= 13,852' + 17.85' (EOP to COE)= 13,869.85' (COE at flag). Change depth counter to read 13,869.85'. Stop at lower flag, depth on.Tag TOC at 14,163' corrected. PUH to 14,000' RBIH to 14,025'. Park coil with COE of retainer at 14,025' MD. MIRU Cementers Pre-set retainer inj rate= 1 bpm/834psi WHP down backside. Pumping down coil- inj rate = 1 bpm/1920psi CTP/834psi WHP. Launch 1/2"steel ball, circ down taking returns. PJSM with all. Ball on seat with 31.4 bbls pumped. (CV=41.6 bbls). FP backside. Set retainer as per Baker. Set 7k down on retainer. Appear good set. Post set retainer inject rate down coil = 1 bpm/841psi CTP. During test-WHP increased from 7psi to 580psi. Appear to be communicating around perfs. Batch up cement. Cement wet at 11:13. Swap pumping over to cementers and pump 5 bbls FW ahead/PT line to 4,500psi/(Zero bbl counter here) 8 bbls 15.8 ppg "G" cement/15 bbls FW behind.Swap to coil pump and pump 35 bbls PowerVis Gel. Coil volume is 41.6 bbls. See pressure increase with lead cement almost 8 bbls from end of coil. Begin squeezing cement walking CTP and WHP up to 2,000psi. Hesitate with 42 bbls pumped. Squeeze pressure bleeding down. Bump pressures up twice more. Concern with over displacing cement with water. Sting out of retainer with 43.3 bbls pumped. Resume pumping laying in fluids on top of retainer,taking returns and slowly reducing WHP and maintaining between 400-500psi. With PowerVis at nozzle, RIH and contaminate 1:1 down to retainer.Tag retainer on depth. Make contamination up pass to 13,400'. RBIH jetting at 3 bpm down to retainer. POOH at 50%chasing returns. With BU at surface see contaminated cement returns for almost 70 bbls before cleaning up. Continue POOH. Swap to 60/40 to FP coil. Lay in 60/40 from 500'to surface in well. At surface, pull up to far above stripper with BHA and fluid escaped. RBIH immediately- report spill to enviro. Close SV, BD, Blow down line to tanks, and Pop off well. LID Baker tools. Tools indicate retainer released as designed. Clean up area outside of containment and estimate 2 gallon spill outside of containment. RDMO CTU. Milne Wells Support RD CT RU from 3-09 and RU END 3-15. NES haul off returns to Milne Ball mill. (660 bbls) 2/10/2018-Saturday No activity to report. 2/11/2018-Sunday No activity to report. 2/12/2018-Monday PT PCE 250#-LOW/2,500#-HIGH. DRIFT TBG W/TEL, 2.50" CENT. &S. BAILER, LOCATED POSSIBLE 5" LTP WHILE PICKING UP TO LOC TT AT 14,446'SLM (12,460' MD) &TAGGED HARD TOP OF CEMENT AT 14,008'SLM (14,018' ELMD, using 10'corr. from gr/ccl ran on 1/16/18) (no sample). SET 4-1/2" BBE SSSV (HNBB-408) IN HXO SVLN AT 1,470' SLM (1,504' MD). 2/13/2018=Tuesday No activity to report. • • S Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 3-09A Slickline 50-029-21780-01-00 195-019 1/5/18 2/22/18 Daily Operations: 2/14/2018-Wednesday No activity to report. 2/15/2018-Thursday PT PCE 250psi LOW/3,000psi HIGH. PULL 4-1/2" BBE *ser#HNBB-408* FROM HXO NIPPLE AT 1,470' SLM (1,504' MD) SET 4-1/2" DMY. SSSV IN HXO NIPPLE AT 1,470' SLM (1,504' MD). 2/16/2018- Friday No activity to report. 2/17/2018-Saturday No activity to report. 2/18/2018-Sunday No activity to report. 2/19/2018- Monday PT PCE 250psi LOW/3,000psi HIGH. PULL 4-1/2" DMY. SSSV FROM HXO NIPPLE AT 1,470' SLM (1,504' MD). SET 4-1/2" QOS *ser#HLQOS-401* IN HXO NIPPLE AT 1,470' SLM (1,504' MD). PULL 4-1/2" QOS *ser#HLQOS-401* FROM HXO NIPPLE AT 1,470' SLM (1,504' MD). 2/20/2018-Tuesday No activity to report. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 3-09A Slickline 50-029-21780-01-00 195-019 1/5/18 2/22/18 Daily Operations: 2/21/2018-Wednesday No activity to report. 2/22/2018-Thursday PT PCE 250psi LOW/3,000psi HIGH. SET 4-1/2" QOS balance operated *ser# HQOS-43* IN HXO NIPPLE AT 1,470'SLM (1,504' MD). 2/23/2018- Friday No activity to report. 2/24/2018-Saturday No activity to report. 2/25/2018-Sunday No activity to report. 2/26/2018- Monday No activity to report. 2/27/2018-Tuesday No activity to report. • oF r, THE • STAT• s Alaska Oil and Gas � " �'— 7� „ALASKA Conservation Commission t>E= = ____ _ 333 West Seventh Avenue it .1tvir' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 0.A.; Q. Main: 907.279.1433 ALA`3� Fax: 907.276.7542 www.aogcc.alaska.gov Bo York SCANNED JAN 1 7 2018 Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Endicott Field, Endicott Oil Pool, Duck IS Unit SDI 3-09A Permit to Drill Number: 195-019 Sundry Number: 317-594 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this-23 day of December, 2017. 1-1:7173/ RECEIVED I . • 0 ORIGINAL OFC . 9F STATE OF ALASKA n'j-5 t2S.,-1 ALASKA OIL AND GAS CONSERVATION COMMISSIONAOGC APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon 0 Plug Perforations Q . Fracture Stimulate ❑ Repair Well 0 Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0 Change Approved Program❑ . Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing 0 Other. Water Shut Off Q. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number Hilcorp Alaska LLC Exploratory ❑ Development Q• 195-019 - 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage Alaska 99503 50-029-21780-01-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O. 462.007 Will planned perforations require a spacing exception? Yes 0 No 0 DUCK IS UNIT SDI 3-09A . 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0047503 - ENDICOTT/ENDICOTT OIL - 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): 14,700' . 10,289' • 14,541' 10,189' 2,050 14,228' N/A Casing Length Size MD TVD Burst Collapse Conductor 161' 30" 161' 161' NIA N/A Surface 2,512' 13-3/8" 2,512' 2,512' 5,020psi 2,260psi Intermediate 10,519' 9-5/8" 10,519' 7,942' 6,870psi 4,760psi Production 4,449' 7" 12,638' 9,153' 7,240psi 5,410psi Liner 2,173' 5" 14,650' 10,256' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(It): See Schematic See Schematic 4-1/2" 12.6#/13 CR/NSCT 12,406' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 9-5/8"x 7"Tie Back&7"x 4.5"SAB-3 and 4.5"HXO SVLN 8,179 MD/6,831 TVD&12,319 MD/8,988 TVD and 1,504 MD!1,504 TVD 12.Attachments: Proposal Summary 0 Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development❑✓ . Service ❑ 14.Estimated Date for a- 15.Well Status after proposed work: Commencing Operations: 1/4/201$ OIL 0 . WIND ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ ❑ Op Shutdown 0 Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York Contact Name: Taylor Wellman 7p./ Authorized Title: Operations Manager Contact Email: iwelimarttthiicoracom Authorized Signature: /V-Z--- Date: 1 t IQC4, 't `7 COMMISSION USE ONLY Contact Phone: 777-8449 Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 31 -- — j9 LI Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ nr S ' , < <' r. :�.0 iv Spacing Exception Required? Yes ❑ No Subsequent Form Required: /6 Li 6 L_/ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: I Z I2. Ii 4 1(.„6;\ Submit Form and iv Form 10-403 Revised 4/2017 Approved application is valid for 12 nths from the date of approval. Attachments in Duplicate , /2.44 _. ; , -,. 1-a • • CT Cement Squeeze Well: END 3-09A PTD: 195-019 Hilcorp Alaska,LL, API: 50-029-21780-01 Well Name: END 3-09A API Number: 50-029-21780-01 Current Status: Shut in Field: Endicott Estimated Start Date: January 4, 2017 Rig: Coil Tubing Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: N/A Regulatory Contact: Tom Fouts Permit to Drill Number: 195-019 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Wyatt Rivard (907) 777-8547 (0) (509) 670-8001 (M) AFE Number: 1724135 WeIIEZ Input Required? Yes Current BHP (Ivishak): 4,104 psi @ 10,000' TVD (Based on BHP taken on 08/15/16) MPSP: 2,050 psi GL System Pressure Brief Well Summary: The well, END 3-09A was sidetracked in 1995. The well had an IBP set to isolate lower perforations and then has had multiple cement squeezes, and perforating above and water shut offs in 1997 and 1998. A production profile was run on this well on 11/28/17 to determine the water producing zones and see if a water shut off is possible. The PPROF indicated 80%of the oil coming from the top perf interval at 13,971'-13,978' md,while 94%of the water was incoming from below 14,000' md. It also indicated that many of the previously squeezed perforations are leaking and are contributing water. Objective: Place a cement plug up to 14,025' and to shutoff water production from the lower intervals and .3( provide additional standoff from water coning. Volumes: Tbg to top perf(no coil in hole) = 218bbls 2" coil tubing x 4-1/2" tbg backside = 0.01133bpf Procedure Slickline 1. RU SL unit and pressure test to 250psi low/2,000 psi high. a. Use GL to pressure test. 2. RIH and pull 4-1/2" BBE SSSV at 1,504' md. a. Description of last SSSV set on 08/15/16: SET 4-1/2 BBE SSSV @1467' SLM, 1504' MD, (ser#HNBB- 43) *****Pkg configuration = btm 2 sets have 1 pc. oversize pkg each side std o-ring, top set has 1 pc. oversize pkg each side oversize o-ring***** 3. RD SL Unit. Coil Tubing 4. MIRU CT unit and spot support equipment. Fill uprights with filtered seawater. 5. Pressure test BOPE to 250psi low/ 2,500 high, 10 min each test. a. Each subsequent test of the lubricator will be to 2,500 psi Hi, 250 Low to confirm no leaks. 6. MU scale jetting nozzle/GR-CCL logging BHA and begin RIH. 7. Once out of the tubing tail, bring pumps online and pump the freeze protect out of the coil. a. Pump rates to be determined by the service tool rep. 8. Once at 13,800' and bring pumps online. Jet between 13,900' — 14,228' md. of a. Vary pump rates, washing speeds, and number of passes as per service tool rep. • . CT Cement Squeeze Well: END 3-09A PTD: 195-019 Hilrurn Alaska.LI, API: 50-029-21780-01 b. Monitor returns for signs of scale. 9. Once set down is reached at the IBP, PU and continue to circulate out any remaining scale in the wellbore. a. IBP was set on 01/02/1997 and has had multiple perfs shot right above and cement squeezes performed above it. The condition of this IBP is unconfirmed if it will hold a solid set down. b. A PPROF was run on 11/28/17 which ended in tagging the IBP/fill,at 14,256'_ELMD. The PPROF also indicated no flow past the IBP but did indicate leaking squeezed perforations. 10. PU, shut down pumps and lightly dry tag IBP at 14,228' md. 11. Log up to 13,875' md. Stop and paint flag on pipe. POOH. 12. Download PDS data, tie into Atlas Segmented Bond Log dated 06-May-1995, and determine PBTD depth. Change cement volume accordingly for TOC depth of 14,025' MD. 13. MU pig shear cementing nozzle BHA and RIH. 14. While RIH, pump down coil and backside to load & kill and flush all gas from the wellbore. Pump a minimum of 250bbls of seawater at max rate. Slow rate and follow with 65bbls of diesel. a. 65bbls of diesel should provide a positive backside pressure of^'100psi with coil in the well. 15. Stop at flag and correct depth. 16. RIH and lightly tag the IBP. Obtain PU weights. 17. Block in backside and begin to pump through coil while taking returns to formation to ensure coil is clear. Shut down pumps, block in backside and begin to mix cement. 18. Once the cement is weighted up to 15.8ppg, pump the following volumes down the coil while taking returns from the backside. a. Lead pig, +/-3.6bbls of cement, tail pig w/ ball, 60/40. 19. Once ball lands on seat, all the cement has exited the nozzle. Shut down pumps and PU 100' above TOC. a. Estimated TOC = 14,025' md. 20. Once out of the cement, pressure up and shear pins on pig shear nozzle. 21. POOH & RD CT. Slickline 22. RU SL unit and pressure test to 250psi low/2,000 psi high. b. Use GL to pressure test. 23. RIH w/memory GR/CCL and tag TQC. 24. Log up from TOC to a minimum of 13,800' md. a. Download data and correlate to the log: Atlas Segmented Bond Log dated 06-May-1995. b. Contact Ops Engineer for discussion if further coil work is needed (see contingencies below for cement cap/underreaming) or if the SSSV can be set. i. If further coil tubing work (cement cap/underreaming) is needed see Contingency 1 & 2. ii. If no further coil tubing work is needed, RIH and set 4-1/2" BBE SSSV at 1,504' md. 1. Description of last SSSV set on 08/15/16: SET 4-1/2 BBE SSSV @1467' SLM, 1504' MD, (ser#HNBB-43) "****Pkg configuration = btm 2 sets have 1 pc. oversize pkg each side std o-ring, top set has 1 pc. oversize pkg each side oversize o-ring***** • � CT Cement Squeeze Well: END 3-09A PTD: 195-019 lcorp Alaska,LL+ API: 50-029-21780-01 25. RD SL Unit. Contingency 1—Coil Tubing Cement Cap Repeat coil tubing steps#12-19, while adjusting cement volumes to place TOC at 14,025' md. Contingency 2—Coil Tubing Underreaming Cement 1. MIRU CT unit and spot support equipment. Fill uprights with filtered seawater. 2. Pressure test BOPE to 250psi low/ 2,500 high, 10 min each test. b. Each subsequent test of the lubricator will be to 2,500 psi Hi, 250 Low to confirm no leaks. 3. MU underreamer BHA and function test as per tool rep. a. Set up blades for running through a min ID=3.725" and working in 7", 26#casing (nominal ID=6.276"). 4. RIH and dry tag the TOC. a. Correct CT depth to the TOC that was confirmed from the SL memory log. 5. PU, bring pumps online and pump freeze protect from coil. Obtain underreaming parameters with slick seawater. 6. Begin underreaming down as per the tool rep. a. Target depth to achieve is 14,025' md. 7. Once target depth is achieved, drop circ ball and pump at high rates while POOH. a. Freeze protect well to 500' while POOH. 8. RD CT unit. • Duck Island Unit • Well: END 3-09A II SCHEMATIC Last Completed: 4/27/1995 Hiker,Alaska.LLCPTD: 195 019 WELLHEAD OPEN HOLE/CEMENT DETAIL KB Elev.:79.4'/GL Elev.:±14.5' McEvoy 13-3/8" 3,254 cu/ft Permafrost in 17.5"Hole 9-5/8" 1,150 cu/ft Class'G'in a 12-1/4"Hole 30. ...,. I [ L7" 112 cu/ft Class"G"in 8-1/2"Hole 5" 1,095 cu/ft Class"G"in 8-1/2"Hole I 1 CASING DETAIL 13-3/8 Size Type Wt/Grade/Conn Drift ID Top Btm 30" Conductor N/A/N/A/N/A N/A Surface 161' 13-3/8" Surface 68/L-80/Btrs 12.415 Surface 2,512' 2 9-5/8" Intermediate 47/NT80s/NSCC 8.681 Surface 10,519' h. 7" Production 26/L-80/LTC-Mod 6.276 8,179' 12,638' 5" Liner 18/L-80/LT&C 4.276 12,477' 14,650' TUBING DETAIL o 4-1/2" Tubing 12.6/13 CR/NSCT 3.958 Surface 12,406' s WELL INCLINATION DETAIL Max Hole Angle=64 deg.@ 8,200' :` Angle at Top Perf=59 Deg.@ 13,971' OX" a JEWELRY DETAIL i. No Depth Item 5 1 1,504' 4.5"HXO SVLN,ID=3.813" I. GLM DETAIL: HES 4-1/2"x 1.5"SPM 9cr y 2 3,574' STA 5:VIv=Dome,Latch=RM,Port=16,TVD= 3,574',5/31/2016 ,I,+ 6 3 4,492' STA 4:VIv=Dome,Latch=RM,Port=16,TVD= 4,479',5/31/2016 /- 1/ 4 5,734' STA 3:VIv=S/O,Latch=RM,Port=24,TVD= 5,509',5/31/2016 7 6i 5 7,441' STA 2:VIv=Dmy,Latch=RA,Port=n/a,TVD= 6,472',4/27/1995 `, 6 8,145' STA 1:VIv=Dmy,Latch=RA,Port=n/a,TVD= 6,808',4/27/1995 9-5/8"a� 7 8,179' TIW 9-5/8"x 7"Tie Back Packer 8 12,307' HES X Landing Nipple,1D=3.813" 9 12,319' 7"x 4.5"Baker SAB-3 Packer 8 10 12,382' HES X Landing Nipple,1D=3.813" MIN ID=3.725" ="R 9 11 12,393' HES XN Landing Nipple,I0=3.725" @12,393'- 10 12 12,404' W LEG-Bottom @ 12,406' XN Nipple '� I.11 13 12,477' 5"HMC Liner Hanger 14 14,228' Baker S-3 IBP-Set 1/2/1997 12 PERFORATION DETAIL 7" A b''13 Sands MD TVD FT Status Shot Sqz Size SPF 13,970'-13,990' 9,866'-9,876' 20 Squeezed 1/24/98 5/2/98 2-7/8" 4 13,974'-13,994' 9,868'-9,878' 20 Open 8/15/98 - 2-7/8" 4 14,002'-14,032' 9,882'-9,898' 30 Squeezed 4/24/98 5/2/98 2-7/8" 4 {'' /F r 14,004'-14,050' 9,884'-9,908' 46 Open 5/13/98 2-7/8" 6 ' C 1 14,034'-14,054' 9,899'-9,910' 20 Squeezed 3/2/98 5/2/98 2-7/8" 6 i *r • 14,062'-14,082' 9,914'-9,925' 20 Open 5/13/98 2-7/8" 6 °R 14,070'-14,100' 9,918'-9,934' 30 Squeezed 4/24/98 5/2/98 2-7/8" 4 14,138'-14,150' 9,955'-9,961' 12 Squeezed 5/8/97 5/2/98 3-3/8" 4 kN I' t4 K2B 14,166'-14,178' 9,970'-9,977' 12 Squeezed 5/8/97 5/2/98 3-3/8" 4 f� 14,192'-14,204' 9,984'-9,991' 12 Squeezed 1/10/97 5/2/98 3-3/8" 4 lV 14,210'-14,214' 9,994'-9,996' 4 Squeezed 4/22/95 5/2/98 2-1/2" 4 9 j _ e 14,210'-14,214' 9,994'-9,996' 4 Squeezed 1/10/97 5/2/98 2-1/2" 4 `ikL7.Y" 1$ 14,220'-14,258' 9,999'-10,020' 38 Squeezed 2/17/96 5/2/98 3-3/8" 6 14,254'-14,258' 10,018'-10,020' 4 Squeezed 4/23/95 5/2/98 3-3/8" 4 14,266'-14,292' 10,025'-10,039' 26 Squeezed 2/17/96 5/2/98 3-3/8" 6 14,308'-14,312' 10,048'-10,050' 4 Squeezed 4/21/95 5/2/98 3-3/8" 4 14,360'-14,364' 10,078'-10,080' 4 Squeezed 4/18/95 4/19/95 3-3/8" 4 14,488'-14,492' 10,129'-10,156' 4 Squeezed 4/19/95 4/19/95 3-3/8" 4 K2A 14,481'-14,490' 10,149'-10,155' 9 Squeezed 10/17/95 10/17/95 3-3/8" 6 5"4. Reference Log:SBT on 4/13/1995 TD=14,700'(MD)/TD=10,280'(TVD) GENERAL WELL INFO SAFETY NOTE: PBTD=14,541'(MD)/PBTD=10,189'(TVD) API:50-029-21780-01-00 H25 Reading Average 230-260 PPM on A/L&Gas Injectors. Sidetracked-4/27/1995 Well Requires a SSSV.Chrome Tbg/Liner&Jewelry Revised By:TDF 112/4/2017 • • Duck Island Unit II Well: END 3-09A PROPOSED SCHEMATIC Last Completed: 4/27/1995 Hilcorn Alaska,LLC PTD: 195-019 WELLHEAD OPEN HOLE/CEMENT DETAIL SAFETY NOTE: KB Elev.:79.4'/GL Elev.:±14.5' McEvoy 13-3/8" 3,254 cu/ft Permafrost in 17.5"Hole H2S Reading Average 230-260 ,., 9-5/8" 1,150 cu/ft Class'G'in a 12-1/4"Hole PPM on A/L&Gas Injectors. 30" :„:41 I 7" 112 cu/ft Class"G"in 8-1/2"Hole Well Requires a SSSV.Chrome 5" 1,095 cu/ft Class"G"in 8-1/2"Hole Tbg/Liner&Jewelry • 1I CASING DETAIL 13-3/8" Size Type Wt/Grade/Conn Drift ID Top Btm 30" Conductor N/A/N/A/N/A N/A Surface 161' 13-3/8" Surface 68/L-80/Btrs 12.415 Surface 2,512' 2 9-5/8" Intermediate 47/NT8Os/NSCC 8.681 Surface 10,519' 7" Production 26/L-80/LTC-Mod 6.276 8,179' 12,638' 5" Liner 18/L-80/LT&C 4.276 12,477' 14,650' TUBING DETAIL 4-1/2" Tubing 12.6/13 CR/NSCT 3.958 Surface 12,406' 3 WELL INCLINATION DETAIL Max Hole Angle=64 deg.@ 8,200' Angle at Top Perf=59 Deg.@ 13,971' JEWELRY DETAIL No Depth Item 5 1 1,504' 4.5"HXO SVLN,10=3.813" GLM DETAIL: HES 4-1/2"x 1.5"SPM 9cr 2 3,574' STA 5:VIv=Dome,Latch=RM,Port=16,TVD= 3,574',5/31/2016 F< 6 3 4,492' STA 4:VIv=Dome,Latch=RM,Port=16,TVD= 4,479',5/31/2016 4 5,734' STA 3:VIv=S/O,Latch=RM,Port=24,TVD= 5,509',5/31/2016 7 5 7,441' STA 2:VIv=Dmy,Latch=RA,Port=n/a,TVD= 6,472',4/27/1995 6 8,145' STA 1:VIv=Dmy,Latch=RA,Port=n/a,TVD= 6,808',4/27/1995 9-5/8".. 7 8,179' TIW 9-5/8"x 7"Tie Back Packer • 8 12,307' HES X Landing Nipple,ID=3.813" 9 12,319' 7"x 4.5"Baker SAB-3 Packer 8 10 12,382' HES X Landing Nipple,ID=3.813" MINID=3.725" "="' 9 11 12,393' HES XN Landing Nipple,ID=3.725" @12,393'- 10 12 12,404' WLEG-Bottom @ 12,406' XN Npple 11 13 12,477' 5"HMC Liner Hanger 14 14,228' Baker S-3 IBP-Set 1/2/1997 12 PERFORATION DETAIL 7" L'' ': 13 Sands MD TVD FT Status Shot Sqz Size SPF 13,970'-13,990' 9,866'-9,876' 20 Squeezed 1/24/98 5/2/98 2-7/8" 4 13,974'-13,994' 9,868'-9,878' 20 Open 8/15/98 - 2-7/8" 4 -.. : ,u� 14,002'-14,032' 9,882'-9,898' 30 Squeezed 4/24/98 5/2/98 2-7/8" 4 > 14,004'-14,025' 9,884'-9,895' 46 Open 5/13/98 - 2-7/8" 6 9:, L 14,025'-14,050' 9,895'-9,908' 46 Squeezed 5/13/98 Future 2-7/8" 6 / 14,034'-14,054' 9,899'-9,910' 20 Squeezed 3/2/98 5/2/98 2-7/8" 6 TOC @14,025' i ! 14,062'-14,082' 9,914'-9,925' 20 Squeezed 5/13/98 Future 2-7/8" 6 " 14,070'-14,100' 9,918'-9,934' 30 Squeezed 4/24/98 5/2/98 2-7/8" 4 K2B 14,138'-14,150' 9,955'-9,961' 12 Squeezed 5/8/97 5/2/98 3-3/8" 4 11111e ' ti.e14,166'-14,178' 9,970'-9,977' 12 Squeezed 5/8/97 5/2/98 3-3/8" 4 1447" 3 (� 150 / 14,192'-14,204' 9,984'-9,991' 12 Squeezed 1/10/97 5/2/98 3-3/8" 4 r cP - 14,210'-14,214' 9,994'-9,996' 4 Squeezed 4/22/95 5/2/98 2-1/2" 4 14,210'-14,214' 9,994'-9,996' 4 Squeezed 1/10/97 5/2/98 2-1/2" 4 14,220'-14,258' 9,999'-10,020' 38 Squeezed 2/17/96 5/2/98 3-3/8" 6 14,254'-14,258' 10,018'-10,020' 4 Squeezed 4/23/95 5/2/98 3-3/8" 4 14,266'-14,292' 10,025'-10,039' 26 Squeezed 2/17/96 5/2/98 3-3/8" 6 14,308'-14,312' 10,048'-10,050' 4 Squeezed 4/21/95 5/2/98 3-3/8" 4 14,360'-14,364' 10,078'-10,080' 4 Squeezed 4/18/95 4/19/95 3-3/8" 4 ' ` r ,11„01 14,488'-14,492' 10,129'-10,156' 4 Squeezed 4/19/95 4/19/95 3-3/8" 4 5 7: ,1i. K2A 14,481'-14,490' 10,149'-10,155' 9 Squeezed 10/17/95 10/17/95 3-3/8" 6 TD=14,700'(MD)/TD=10,280'(TVD) Reference Log:SBT on 4/13/1995 PBTD=14,541'(MD)/PBTD=10,189'(TVD) GENERAL WELL INFO API:50-029-21780-01-00 Revised By:TDF 112/4/2017 Sidetracked-4/27/1995 • • 2.5‘.--6-15 II Seth Nolan Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 100 RECEIVEDAnchorage, AK 99503 Tele: 907 777-8308 Hik9lrp:tb`pka.LTA. Fax: 907 777-8510 DEC 15 2017 E-mail: snolan@hilcorp.com DATA LOGGED \ /A/201 ®GCC i41 K BENDER DATE 12/08/2017 To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SDI 3-09A Prints: GR/CCL/TEMP/PRESS/GRADIO/ILS/DEFT/FBS/X-Y CAL CD Hilcorp END3-09A PPROF_23NOV17_FINAL 11/30/20179:17 AM File folder SCANNED FEB D 62018 Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: o4ate: • „_,...._ ..,. .A-_,...„».-.,.�mnac � ... a ..- a,.,.... .........3e - ._, _...,.... .o...E..,..... _ y ,,,,. .. ,......, ...a� ..,. ,.. T.. ..._ .�..w.1n�c� • • or ��\1//% . THE STATE Alaska ,. Gas vi 1,, Conservation Commission 5 W333 West Seventh Avenue 7GOVERNOR BILL WALKERAnchorage,e Alaska 99501-3572 ‘111747('S., Main: 907.279.1433 °'1gI.A e-'0' Fax: 907.276.7542 www.aogcc.alaska.gov February 28, 2017 Mr. John Barnes Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 r Re: Docket Number: OTH-16-024 suttee MAR 2 121 E7, Defeated Safet Valve S stem Duck Is and Unit 3-09A (PTD 1950190) Duck Island Unit 2-56A (PTD 1980580) Dear Mr. Barnes: The Alaska Oil and Gas Conservation Commission AOGCC has reviewed Hilcorp Alaska LLC (Hilcorp)'s February 23, 2017 letter outlining corrective actions taken in response to the notice of violation for defeated SVS dated September 14, 2016 and subsequent letter dated October 14, 2016. The corrective actions — handover procedures, standardized defeated SVS tags, visual indicators for hydraulic isolation valves, and installation of quarter turn valves for SVS hydraulic isolation — were completed by February 18, 2017. The AOGCC is satisfied with the corrective actions implemented by Hilcorp which are intended to prevent recurrence of this noncompliance. The AOGCC does not intend to pursue any further enforcement action regarding these Duck Island Unit defeated SVS. Sincerely, 0/4 P29"<-4kk...../ Cathy/P. Foerster Chair cc: AOGCC Inspectors(via email) • • Docket Number: OTH-16-024 Defeated Safety Valve System-Closeout February 28,2017 Page 2 of 2 RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision denying reconsideration,UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather,the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. S Regg, James B (DOA) From: Bixby, Brian D (DOA) _f)(00 Sent: Thursday, March 02, 2017 5:46 AM ( To: Regg, James B (DOA) Subject: RE: Hilcorp Corrective Actions in Lieu of Qtr Turn Valves Jim, I made it out to Endicott yesterday afternoon and looked at these bars on the panels with Kendell (Pad Operator). I'm totally comfortable with this design fora good visual to determine the position of the valves. Even if the needle valve is only a couple turns closed the bar will not fit on them. So a quick glance at the bar and you can tell all the valves are fully open if the bar is in place. I reading the letter I thought they had said they installed 1/4 turn valves is the only reason I brought up the issue. Should you need anything else please let me know. Thanks, • Brian Brian Bixby Petroleum Inspector Cell 509-998-3683 brian.bixby@alaska.gov 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 Brian Bixby at(907) 279-1433 or brian.bixby@alaska.gov. From: Regg,James B (DOA) Sent: Wednesday, March 01, 2017 12:29 PM To: Bixby, Brian D (DOA)<brian.bixby@alaska.gov> Subject: Hilcorp Corrective Actions in Lieu of Qtr Turn Valves Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 • CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, 1 • • • Hilcorp Alaska, LLC John Barnes Asset Team Leader Post Office Box 244027 Anchorage,AK 99524-4027 FED 2 4 ?Oil 3800 Centerpoint Drive Suite 100 Anchorage,AK 99503 February 23, 2017 AOGGC Phone: 907/777-8350 Fax: 907/777-8351 jbarnes@hilcorp.com Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Docket No. OTH-16-024 Defeated Safety Valve System Duck Island Unit 3-09A(PTD 1950190) Duck Island Unit 2-56A(PTD 1980580) Dear Commissioner Foerster, Hilcorp Alaska, LLC, provides follow-up to our November 18, 2016 letter regarding progress on corrective action items for defeated safety systems on END 3-09A and END 2-56A. We have included details on the closeout of all remaining corrective actions. All Corrective Actions Complete as of February 18,2017 Handover Procedures Changes—Completed 9/22/16 as detailed in 11/18/16 letter Standardized Defeated SVS Tags—Completed 11/14/16 as detailed in 11/18/16.letter Visual Indicators for Hydraulic Isolation Valves at SVS Panel—Completed 2/18/17 We have completed our work to verify that SVS hydraulic isolation valves have a clear visual indicator of Open/Closed status at the panel. These indicators will prevent oversight of inadvertently defeated SVS components. Endicott: Endicott SVS panels utilize needle valves for hydraulic isolation of the SVS. Installation of"Valve Open Bars" that can only be installed when needle valves are fully open will ensure clear visual indication of operational SVS at the panel. Any new wells or non-operable wells that are returned to service will either have "Valve Open Bars" or quarter turn valves installed on the panel. We completed the installation of bars on all operable producers and injectors by 2/18/17 Northstar: Completed on 10/24/16 as detailed in 11/18/16 letter. Milne Point: Verified as detailed in 11/18/16 letter. • • Docket No.OTH-16-024 February 23,2017 Page 2 of 2 Quarter Turn Valves for SVS Hydraulic Isolation at Well Tree—Completed 2/18/17: Quarter turn valves have been installed exclusively for hydraulic isolation of the SVS at the well tree to prevent oversight of inadvertently defeated SVS components. Endicott: All SSV control lines were verified to have quarter turns already installed for isolation at the tree. All the SSSV control & balance isolation valves were mechanically locked open with a quarter turn valve stacked in line with the needle valve. Substitution of quarter turns on every operational well at Endicott was by completed 2/8/17. p Northstar: SSV and the SSSV control line isolation valves were swapped with quarter turn valves on all wells at Northstar by 12/31/16. A single needle valve was left installed in the cellar below ground level but is not used for primary isolation of the SSSV hydraulic line and is not accessible for routine well work. Milne Point: All but 20 wells at Milne Point already utilize quarter turns for SSV isolation at the tree. We completed swapping the remaining 20 wells to quarter turn valves on 11/5/16. Four wells at Milne Point are equipped with surface controlled SSSVs; a quarter turn valve was substituted for hydraulic isolation at the tree on all four of these wells by 1/23/17. We have completed all solutions referenced in the original October 3, 2016, written explanation. If you have any additional questions, please contact Wyatt Rivard at 777-8547 or by email at wrivard@hilcorp.com. ' nce ely, AC CORP ALASKA, LLC John Barnes Asset Team Leader i Regg, James B (DOA) From: Regg,James B (DOA) tL`2ii\I Sent: Tuesday, November 22, 2016 8:48 AM To: DOA AOGCC Prudhoe Bay Subject: Defeated SVS - Hilcorp Corrective Actions Attachments: Hilcorp OTH-16-024 Defeated SVS DIU 3-09A (PTD 1950190) and DIU 2-56A (P....pdf There were 2 defeated SVS at Endicott recently.Wrote a notice of violation requiring corrective actions. Hilcorp provided the required response dated October 14 summarizing what they intend to do,which I replied that the AOGCC will not close this enforcement until all corrective actions have been implemented. This is work in progress—attached is a copy of a letter highlighting partial completion of corrective actions; for your review. When at Milne, Endicott,and Northstar please confirm the corrective actions are in place. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. 1 • • Hilcorp Alaska,LLCJohn Barnes ?�(* _ Asset Team Leader Post Office Box 244027 )016 Anchorage,AK 99524-4027 3800 Centerpoint Drive Suite 100 November 18, 2016 Anchorage,AK 99503 Phone: 907/777-8350 Cathy7-8351 Foerster, Chair Fax: es@hil907/7orp.co jbarnes@hilcorp.com Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Docket No. OTH-16-024 Defeated Safety Valve System Duck Island Unit 3-09A (PTD 1950190) Duck Island Unit 2-56A (PTD 1980580) Dear Commissioner Foerster, Hilcorp Alaska, LLC, responds to your October 14, 2016, letter regarding the defeated safety systems on END 3-09A and END 2-56A. We provide information regarding our progress on corrective actions as of November 18, 2016, along with updated timelines for the remaining corrective actions. Progress of Corrective Actions as of November 18,2016 Handover Procedures Changes—Completed 9/22/16 We have fully rolled out procedural changes to utilize and document function tests of the SVS following wellwork in all three North Slope fields as of 9/22/16. Mandatory function tests following wellwork ensure that inadvertently defeated SVS components are identified and either normalized or properly tagged prior to the well being brought online. Standardized Defeated SVS Tags—Completed 11/14/16 The use of standardized tags will ensure that defeated SVS components are tagged with consistent information as required as by 20 AAC 25.265(m). The bright yellow tags provide a clear indicator of the defeated system and standardization avoids the ambiguity of other types of flagging or caution tags. We have provided and implemented the new tags in all three fields as of 11/14/16. Visual Indicators for Hydraulic Isolation Valves at SVS Panel—In Progress We are continuing our work to verify that the valves used for hydraulic isolation of the SVS system at the panel have a clear visual indicator of Open/Closed status. These indicators will prevent oversight of inadvertently defeated SVS components at the panel. Docket No.OTH-16-024 • October 3,2016 Page 2 of 3 Endicott: Endicott SVS panels utilize needle valves for hydraulic isolation of the SVS. Installation of"Valve Open Bars" that can only be installed when needle valves are fully open will ensure clear visual indication of operational SVS at the panel. We completed the installation of bars on all operable producers on 11/9/16. We anticipate completion of the installation on remaining operable wells by 1/1/17. Northstar: Northstar SVS panels also utilize needle valves for hydraulic isolation of the SVS. We completed the installation of"Valve Open Bars"on all Northstar wells(with the exception of suspended well NS-26)on 10/24/16. We provide pictures of bars installed on each well panel in Attachment 1. Milne Point: Milne point SVS panels already utilize quarter turn valves for hydraulic isolation. Quarter turns provide clear indication of Open/Closed status. Quarter Turn Valves for SVS Hydraulic Isolation at Well Tree—In Progress: Quarter turn valves will be used exclusively for hydraulic isolation of the SVS at the well tree to prevent oversight of inadvertently defeated SVS components. Endicott: We have begun the process of mechanically locking open the SSSV control & balance isolation needle valves and substituting with quarter turn valves on every operational well at Endicott. We anticipate completion of the installation by 2/1/17. All SSV control lines already have quarter turns installed for isolation at the tree. Northstar: We have begun replacing both the SSV and the SSSV control line isolation valves with quarter turns at the trees at Northstar. We anticipate completion of the replacements by 2/1/17. Milne Point: All but 20 wells at Milne Point already utilize quarter turns for SSV isolation at the tree. We completed swapping the remaining 20 wells to quarter turn valves on 11/5/16, and include the service reports in Attachment 2. Additionally, we will swap the three wells at Milne Point with surface controlled SSSVs to quarter turns for isolation at the tree. We anticipate completion of the replacements by 12/1/16 We will continue providing updates until we have completed all solutions referenced in the October 3, 2016, written explanation. If you have any additional questions, please contact Wyatt Rivard at 777-8547 or by email at wrivard@hilcorp.com. Sincerely, IL ORP LASKA, LLC ohn Barnes 11 Asset Team Leader • Docket No. OTH-16-024 October 3,2016 Page 3 of 3 Attachments: 1) Northstar SVS Panel "Valve Open Bar" Photos 2) Milne Point Quarter Turn Well Service Reports Attachment ilorthstar SVS Panel "Valve 01n Bar" Photos PNOOUCER PANEL :m+..=, - IJ9 Si—D7 PRODUCER„;, • ;.. PANEL PRODUCER WELL- p. ,� PANEL e, I NS - 06 , _. . n,. ,,'01 'Ir , .V.,' -2:-„,:::•-'ii';',e,,,,,, ','„„ '..) ,, i ,A fid ' .''''" 4,4111k1, •,,i,-- It, - . ) . rst riiiiii5„?,,, ,.-i, -,,,; '1fTr} R . 3 ' .„.44, '5.t4.x� e3c .. } i'PC X 9 1 — f5t r WELLHbUS"E 'RWELLHOUSE • CONTROL PANEL CONTROL PANEL WELLHOUSE IJ8-53-7308_., IJR-S3-7309 _ _ CONTROL PANEL PRODUCER PRODUCER IJB-S3-731O PANEL PANEL _ INJECTOR PANEL � ,�, 41,E N§709W�LL ■■■■■■ wE...Li 4= NS-"1 i Y ;� ! Y xN� J 0 .,t ki VI V.L.,111/...1' 1 1 'Lf. ';'"Ca__ WELL HOUSE Ir CONTROL PANEL. ? IJB-S3-7312 �;_ .. : .a„�_ `S '..4 PRnnic_; Attachment eorthstar SVS Panel "Valve Oon Bar" Photos CONTROL PANEL' ( i WELLHOUSE IJB-S3-7314 ri-4 Y CONTROL PANEL PRODUCER 1,2B-S3-7316 PANEL PRODUCER :.< F ; H` ,> PRODUCER �LL ��* PANELPRODUCER WELL NS-14 NS-15 NS-16 ,-,, '- =--- 'k- a--i,--' l'" 0 Y , _i i . --- ,,„:.<12,-,-- •,. i:\,,:fi ' 'A 1 WELL HOUSE PRODUCER PRODUCER ' ! CONTROL PANEL PANEL . PANEL IJB S3 7317 =°v INJECTOR 1 . ;, . .. a E �„�" '� NS-19 PANEL • WELL NS-17 .. Y; ili 110 ,041l� , I 4t,5,-" c' PRODUCER PANEL' PRODUCER IITRo_FA.:EL _ c :3 21 PANEL '. PRODUCER L2, PANEL 7 .,....-__. _ _.__ I'« [ g i I • i• \:. ` �. aid d:.'�L.fP.'J+CH4 , i€f � Page 2 of 4 Attachment Viorthstar SVS Panel "Valve 0, Bar" Photos WELLHOUSE ' CONTROL PANEL PRODUCER ; . IJB—S3-7325 _- • it ,. PANEL riirr g -.;:z.,..60-p444 wont ,', YE L , INJECTOR PANEL NS-24 ! WELL "' w[ aus[ /' CONTROL PNAL -,, .A 733. 1Z � N 1 WELL .. �+ . NS-23 , j r , .411 i . ,_. ,f,. . _ ._ _....),,,,,,..„„zie i _.....,.. . , ,,,, ,.,.... .u...,,,, _ „...., T 21,,....,, , _. . a1 ► GAS INJ [ ��''��( _. � c a 1' 1' WELL HOUSE - i/,' CONTROL PANEL ._- '. ,. IJB-53-29 E INJECTOR { .• �rti5 :',1i,'. PANEL i sit ✓tom J f _' �.i !ti" fix, • flri r its s. , A_..,,.. ,,,. . . ..? J�+ - i 'Y. ti J ±� 1 < WELL- -.' ''',.t.,;,..,..4.,.,.1.;4-:„... S-31 WELLHOUSE 'NI Si- 30 - -:'-'- • CONTROL PANEL IJB-S3-7335 • INJECTOR PANEL t NS'JG r ',' .Z v' •r - . r , a'i. r Page 3 of 4 Attachment#Jorthstar SVS Panel "Valve n Bar" Photos sx ; �C3UCER PANEL =PRODUCER PANELS 5-33 •r • a. YIOle Ofp ,.,� �Fy .�•,""'�+ Y � vn � ��o��r on � Page 4 of 4 Attachment Point Quarter Turn WellQrvice Reports Well Service Report ililcorp Alaska,LLC Well 13-23 Field Milne Date 11/3/2016 Job Scope Installed Swagelok Quarter Turn Valve WSM Bill Kruskie Crew Supervisor Cody York Service Pr AES Daily Summary Installed new Swagelok cold temp quarter turn valve/valves on the SSV and function tested on wells B-23, B-10 B-09, B-18, B-21, B-15, B-05, B-04, B-03. Fluid Level Tag Operations Log Initial Tbg/ IA/OA Press Time Depth Operation Entry Final Tbg/IA/OA Press Job Costs Service Company/ Equipment Daily Cost Cumulative Total Total Field Estimate Page 1 of 5 Attachment 1ilne Point Quarter Turn WellQrvice Reports Well Service Report111 1Bkora Alaska,LLC Well F-79 Field Milne Date 11/5/2016 Job Scop Installed Swagelok Quarter Turn Valve WSM Bill Kruskie Crew Supervisor Cody York Service Provider AES Daily Summary Installed new Swagelok cold temp quarter turn valve/valves on the SSV and function tested (passed) on wells. F- 79, F-86, F-87, F-89, F-90, F-91, F-93, F-94 Fluid Level I Tag Depth Operations Log Initial Tbg / IA/OA Press Time Depth Operation Entry Final Tbg /IA/ OA Press Job Costs Service Company/ Equipment Daily Cost Cumulative Total Total Field Estimate Page 2 of 5 Attachmentilne Point Quarter Turn Well•rvice Reports Well Service Report Hileorp Alaska,LLC Well G-17 Field Milne Date 11/3/2016 Job Scopi Installed Swagelok Quarter Turn Valve WSM Bill Kruskie (Crew Supervisor Cody York Service Provider IAES Daily Summary Installed new Swagelok cold temp quarter turn valve/valves on the SSV and function tested. Fluid Level Tag Depth Operations Log Initial Tbg/ IA/OA Press Time Depth Operation Entry Final Tbg / IA/OA Press Job Costs Service Company/ Equipment Daily Cost Cumulative Total Total Field Estimate Page 3 of 5 Attachment Siiiine Point Quarter Turn Well•rvice Reports Well Service Report11 Ilitcorp Alaska,LLC I. I_. 1..•. I i ricii �-v2 Irleiu minim luate 1'1%.9/LU"Ib Job Scop Installed Swagelok Quarter Turn Valve WSM Bill Kruskie 1Crew Supervisor Cody York Service Provider AES Daily Summary Installed new Swagelok cold temp quarter turn valve/valves on the SSV and function tested. Fluid Level Tag Depth Operations Log Initial Tbg/ IA/OA Press I Time Depth Operation Entry Final Tbg/ IA/OA Press Job Costs Service Company/ Equipment Daily Cost Cumulative Total Total Field Estimate Page 4 of 5 Attachmentilne Point Quarter Turn Weleervice Reports Well Service Report IMora Alaska,I Well J-18 Field Milne Date 11/3/2016 Job Scope Installed Swagelok Quarter Turn Valve WSM Bill Kruskie 'Crew Supervisor Cody York Service Provider IAES Daily Summary Installed new Swagelok cold temp quarter turn valve/valves on the SSV and function tested. Fluid Level Tag Depth Operations Log Initial TIN/ IA/OA Press Time Depth Operation Entry Final Tbg/ IA/OA Press � I Job Costs Service Company/ Equipment Daily Cost Cumulative Total Total Field Estimate Page 5 of 5 • or 4,1 I//%y � THE STATE Alaska Oil and Gas �-4'' 4 Conservation Commission eOh 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 �' Main: 907.279.1433 Fax: 907.276.7542 www,aogcc.alaska.gov October 14, 2016 Mr. John Barnes Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 Re: Docket Number: OTH-16-024 Defeated Safety Valve System Duck Island Unit 3-09A (PTD 1950190) Duck Island Unit 2-56A (PTD 1980580) Dear Mr. Barnes: The Alaska Oil and Gas Conservation Commission (AOGCC) reviewed Hilcorp Alaska, LLC (Hilcorp)'s October 3, 2016 written explanation regarding the safety valve system violations on Duck Island Unit (DIU) wells 3-09A and 2-56A.1 AOGCC became aware of the DIU 2-56A violation (failure to install a subsurface safety valve; failure to tag the well) after issuance of the DIU 3-09A notice of violation(defeated safety valve system) and advised Hilcorp representatives during a September 19, 2016 meeting that it would not issue a separate notice of violation. Instead, Hilcorp was instructed to address the DIU 2-56A violation in its response to the DIU 3-09A notice of violation. In its responses to numerous past notices of violations Hilcorp committed to complete corrective actions to prevent recurrence of the violations at the DIU wells. Recent examples of its commitment include Hilcorp's responses to the defeated safety valve system at Northstar 15 in February 2015,two defeated alternate safety valve systems at Soldotna Creek Unit rod pump wells (January 2014), and the defeated safety valve system at Sterling 43-09X (April 2013). AOGCC closed out these violations based on Hilcorp's commitment to complete corrective actions. Evidence suggests that Hilcorp's emphasis on training its operating personnel and other corrective actions have been ineffective at preventing recurrences at Hilcorp. Hilcorp now indicates that corrective actions may take up to six months to complete. AOGCC intends to monitor implementation of Hilcorp's corrective actions as outlined in the October 3, 2016 response to the notice of violation for safety valve system violations at DIU. For the present, AOGCC will take no action. However,unless Hilcorp has demonstrated to AOGCC's satisfaction by April 15, 2017 that corrective actions sufficient to prevent recurrences of these violations have been implemented, the AOGCC will move forward on this matter. Both wells are located on Endicott Satellite Drilling Island • • Docket Number:OTH-16-024 Defeated Safety Valve System October 14,2016 Page 2 of 2 Please direct any questions you have regarding this to Jim Regg at(907) 736-1236. Sincerely, /619C1614/7",— Cathy P. oerster Chair cc: AOGCC Inspectors (via email) RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision denying reconsideration,UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather,the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. • • Hilcorp Alaska, LLC John Barnes Asset Team Leader Post Office Box 244027 Anchorage,AK 99524-4027 3800 Centerpoint Drive Suite 100 October 3, 2016 Anchorage,AK 99503 Phone: 907/777-8350 Fax:907/777-8351 Cathy Foerster, Chair jbarnes@hilcorp.com Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 995014. fr' A Re: Docket No. OTH-16-024 Defeated Safety Valve System 1 Duck Island Unit 3-09A (PTD 1950190) Duck Island Unit 2-56A (PTD 1980580) Dear Commissioner Foerster, Hilcorp Alaska, LLC ("Hilcorp") responds to your September 14, 2016, letter regarding the defeated safetysystem on END y 3-09A. In addition, as per our meeting with Jim Regg on September 19, 2016, we also provide details regarding the removed but untagged subsurface safety valve on 2-56A. Description of Events Duck Island Unit 3-09A Endicott well 3-09A is a gas lifted producer that was shut-in on July 29, 2016 in conjunction with scheduled Endicott plant maintenance that occurred from July 29th to August 20th. During the plant shut-down, a Static Bottom Hole Pressure Survey (SBHPS) was run which required removing the surface controlled subsurface safety valve (SCSSSV) on August 15th. The SCSSSV was reinstalled on August 22°1. At 9 am Operations was notified that the well was ready to put on production. The well was then brought online and stabilized quickly. The AOGCC inspector was already onsite to witness SVS and MIT testing on nine other wells. Hilcorp decided to also test END 3-09A at the same time. At around 2 pm, the well was shut in for testing and the Pressure Safety Low (PSL) detection device was bled down until it tripped at 193 psi. Upon tripping the PSL, the Surface Safety Valve (SSV) closed and held differential pressure but the SCSSSV stayed pressured up. The SSSV Control Supply Valve was found to be blocked in at the panel. The AOGCC inspector was notified and then the panel was normaled and the SVS system retested successfully. Duck Island Unit 2-56A Endicott well 2-56A is a low rate gas lifted producer that was shut-in on March 20, 2016. The well's SCSSSV was pulled on May 24th in preparation for a SBHPS that was logged during the plant shut-down. The valve could not be reinstalled immediately due to lack of redressed valves. The well's wing valve was tagged on May 25th as needing an SVS performance test once returned to production but the SCSSSV was not tagged. On September 9t the well was returned a M Docket No.OTH-16-024 October 3,2016 Page 2 of 5 to production but it was not recognized that the SCSSSV had been removed. An AOGCC performance test was scheduled and the witnessed waived test was performed on September 12th The SSV tested successfully and then the pressure was bled down above the SCSSSV. There was no increase in tubing pressure and SCSSSV was recorded as a pass on the SVS test form. The operator then attempted to open the SCSSSV but could not pressure back up suggesting a loss of control line integrity. The well was left shut-in and on September 14th operations determined that SCSSSV had not been reinstalled and that what appeared to be a passing test was actually the well dying without the assistance of gas lift. The AOGCC was notified on September 14th of the removed but untagged valve and on September 16th a SCSSSV was successfully installed. A passing AOGCC witnessed SVS test was obtained on September 16th Cause of Incidents Both incidents resulted from failures in the well handover process following downhole well work. When control of the wells' SVS wasgiven back to operations ope from wireline,the SCSSSV should havee b en either confirmed as operational or properly tagged as defeated prior to the wells being brought back online. This failure to confirm the SVS system can be attributed to a combination of operational oversight and a lack of a formal procedure. The SVS systems on both END 3-09A and END 2-56A utilize needle valves for the purposes of hydraulic isolation. The open/closed status of needle valves is not immediately apparent and it is possible to mistakenly leave the system in a defeated state. The best way to verify that a SVS system is not defeated is to perform a function test that demonstrates that the PSL, control panel and the safety valves operate. If any SVS component is to be left defeated, our procedure is that it must be properly tagged with the information required by 20 AAC 25.265(m). This did not happen in this case. A function test would have quickly identified the defeated SSSV Control Supply Valve on END 3-09A. Similarly, a function test on END 2-56A following the removal of the SCSSSV would have confirmed the function of the SSV while ensuring the SCSSSV was properly tagged as defeated. Despite the value of a function test following wellwork,there was no formal process in place at Endicott to conduct and document these tests. Prevention of Future Occurrences We have implemented or are in the process of implementing a combination of administrative and engineering solutions across all three North Slope fields to prevent future occurrences: Incident Review Hilcorp has prepared and distributed incident reports of the failures to field operations personnel at Northstar, Endicott and Milne Point on August 31St and September 16th for END 3-09A and END 2-56A respectively. Docket No. OTH-16-024 October 3,2016 Page 3 of 5 Use of Hilcorp Alaska Defeated SVS Tags Northstar, Endicott and Milne Point will begin using a standardized tag for defeated safety valve systems. The tag includes all of the information required as per 20 AAC 25.265(m). The tag is already in use in Hilcorp's other Alaska fields. Weliwork Handover Processes Including Function Test of SVS In both incidents, a function test of the SVS system following wellwork would have identified defeated systems that were missed otherwise. Going forward, a formal process has been either implemented or verified to be in place for all three North Slope fields: Endicott Endicott's "Hilcorp Well Release Form" (See Attachment 1) is now required to be used after every wellwork handover. The one page checklist includes a function test of safety system components. If any components are left defeated,they must be tagged. - The form was created following the END 3-09A incident but was not in use during the 2-56A well handover in May. - The form has been rolled out with training provided to both shifts of field personnel on September 16th and September 22nd - Form was used on September 16th and September 17th to check every well at Endicott. Operations verified no other systems were left inadvertently defeated during turnaround well work. Northstar Function testing was the main action item from the defeated SSV incident on NS-15 on January 17, 2015. Following that incident, the "NSI Prod Well Turnover"procedure was modified to include a function testing step. - The procedure was revised again following the incidents at Endicott with the function test also added to a quick reference checklist within the procedure. Milne Point Unlike Northstar and Endicott, Milne Point experiences a high volume of wellwork over many well pads during both day and nighttime operations. To help assist with communicating defeated SVS between pad operators, the existing daily read sheets or "Pad Shift Logs" were modified to include tracking of SVS defeated for wellwork. - Well Numbers are recorded on the logs when wellwork is being conducted and SVS are defeated. - Records of wells with defeated SVS are transferred from one shift log to the next as the pad is passed between day/night operators. - Only when the wellwork is complete and the SVS is function tested, does the record come off of the shift log. • Docket No. OTH-16-024 October 3,2016 Page 4 of 5 Engineering Solutions for Identification of Defeated SVS Components Operational oversight of defeated/removed SVS components contributed to both incidents. Going forward, engineering fixes will be implemented at all three of Hilcorp's North Slope Fields to help with simple, visual verification of open and operational SVS components. Endicott Endicott has identified several engineering solutions to either improve identification of needle valve position or to install quarter turn valves to be used instead of needle valves. Additionally, Endicott control room software has been modified to track SSSV status. - Needle valves that are used for SCSSSV control and balance line isolation at the well tree will be mechanically locked open and an additional quarter turn valve will be stacked and used for better visual indication of open/closed status. SSV hydraulic lines are already isolated with quarter turn valves. - SVS control panels will have a"Valve Open Bar" (see Attachment 2) installed behind the SSSV Control Supply, SSV Control Supply and Wing Valve Control Supply needle valves when the valves are open. This solution provides a clear visual guarantee that SSV, SCSSSV and wing valve are operational at the panel. o Endicott panel needle valve stems offer —.35" inches of clearance when open and the 5/16" bar will only fit behind the valve handles when valves are fully open(See Attachment 3). o When the well is online, the panel will either have the bar installed or a defeated tag explaining why. o With this solution, needle valves need not be swapped out at the panel to get a visual indication. Needle valves are preferable at the panel for precision control during actuator diagnostics and to prevent crushing hydraulic filters and shocking actuators when opening/closing valves. - Endicott control room board operators now have an"SSSV"or"No SSSV" option for each well in their software. When an SSSV is removed "No SSSV" is selected. If the well is brought online in this state, it flags the operator with a warning regarding the missing SSSV. Additionally, a 14 day software timer can be set as a reminder while waiting on installation of a downhole valve. Northstar Northstar also utilizes needle valves for hydraulic isolation of the safety valves at both the panel and the tree. Identification of isolation valve position can similarly be achieved by installing and utilizing quarter turn valves instead of the needle valves at the tree and utilizing a"Valve Open Bar" at the panel. - Needle valves used for both SCSSV and SSV hydraulic isolation at the tree will be swapped to quarter turn valves for better visual indication of open/closed status. - As with Endicott, SVS control panels will have a "Valve Open Bar" to provide a clear, fail-safe indication that SVS and wing valve are operational. Exact dimensions/thicknesses may vary from Endicott design. When the well is online, the panel will either have the bar installed or a defeated tag explaining why. • Docket No.OTH-16-024 • October 3,2016 Page 5 of 5 Milne Point Safety valve panels at Milne Point are already equipped with quarter turn isolation valves for good visual indication of valve position. Any existing needle valves used for hydraulic isolation of the SSV at the tree will be swapped for quarter turns. - Some SSV hydraulic tie-ins for wireline currently utilize needle valves for isolation. These will be swapped for quarter turns. - There are only 3 wells with SCSSSV's at Milne point: MPE-02, MPE-03 and MPF- 99. Any isolation valves on the SCSSSV control lines will also be replaced with quarter turn valves at the tree. Timeline for Corrective Actions Handover Procedures Changes Procedural changes to utilize and document function tests of the SVS following wellwork have been fully rolled out in all three North Slope fields. The distribution and use of standardized Defeated SVS tags is expected to take four weeks. SVS "Valve Open Bar" Installation The fabrication and installation of bars for all well SVS panels at Endicott and Northstar is expected to take three months. Installing Quarter Turn Valves For SVS Isolation at Tree Distribution and installation of quarter turn valves for SVS isolation at the tree on every well at Endicott,Northstar and Milne Point is expected to take six months. Once corrective actions are implemented, a follow-up letter will be provided to the AOGCC confirming completion. If you have any additional questions, please contact Wyatt Rivard at 777-8547 or by email at wrivard@hilcorp.com. Sincerely, LCORP ALASKA, LLC • ill ehn Barnes Asset Team Leader Attachments: 1) Hilcorp Well Release Form 2) "Valve Open Bar"Installation at Endicott 3) Open/Closed Needle Valve Measurements at Endicott • Attachment 1: Hilcorp Well Release Form HILCORP WELL RELEASE FORM Location: Well#: Date: Company: Operation: Contact Info: Personnel: Brief Job Disc ription: PRE SITE INSPECTION: Location Clean: SIMOPS: Well On Line: Visible Spills: Well House Condition: Well Cellar Clean: SVS System On line: POST SITE INSPECTION: Location Clean: SIMOPS: Well On Line: Visible Spills: Well House Condition: Well Cellar Clean: Roof Doors Closed: Safety System Check List: SVS Panel Operational: Master Valve Open: Main Supply&Return Valves Open: Swab Valve Closed: SSSV Supply Open: Tree Cap installed&Tested: SSSV Vent Closed: SSSV Tree Control Open&Zip Tied: SSV Supply Open: SSSV Tree Balance Open&Zip red: SW Vent Closed: IA Gate Valve Open: SSV Three Valve Lined Up To Panel: IA Gauge Valve Open: SSV Fusable Removed: OA Gate Valve Open: PSI.Switch In Normal: OA Gauge Valve Open: PSI.ROOT Valve Open: OOA Gate Valve Open: SSSV Installed and Pretested: OOA Gauge Valve Open: SVS Pre-Test Function Complete: All Bleeds Closed: SVS Panel Valve Open Bar In Place: Any Defeated SVS Are Tagged: REMARKS: Operations Signature: Date: • 0 $., cs CA 44 I >• >-. la ';';',4'..ti°1,-:',:,%;i1".,,,:,'. 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C.4 C..) 1 '''''''', '' = ii> cs -1i w f.-di 1.4 . , ... , O ....:. , ...... r ..,-,....„ ,...,,, --------- .) t.. . . .: • / " -'.„ sts • .., 0 0 >• an '',.-t.•'.':'t;- '' CZ = > . 3 P" la ';' • 0 miliemik 1,- to M 0 Y C y w k moms a) +, "c-' E ti C, a a) C r,, v Si c h= a. rnJrt 'k azz.m. _ ' / jJ Li, Q J' W i V W ^.1 "CI r „ cLo f tiosh' `, w,,,,. , Z 04 a M o a 2 r l �, .1,N; `,, 1/,,,,,,,,, p C03 E Gr ® --*www - ` , .. at ec. M i i c7 E 5 as ,a cu c '" c n . I, J a Z 4 w RECEIV sEP 19 2016 Incident Description AOGCC — Improperly Defeated SVS — Event Date: 26 August 2016 Hilcorp Alaska, LLC Location: END 3-09A, Endicott Description: The sub surface safety valve (SSSV) was pulled from END 3-09A in support of a bottom hole pressure survey conducted during the Endicott turnaround. The SSSV was reinstalled with Slickline on 8-26-16 and, at 9 am, Operations was notified that well could be brought online. AOGCC was already onsite to witness mechanical integrity testing and Safety Valve System (SVS) tests for nine other wells. 3-09 was brought online while regulatory testing was ongoing and stabilized quickly. It was decided to test 3-09 along with the other wells while AOGCC inspectors were onsite. At around 2 pm, well was SI for testing and PSL was bled down until it tripped at 193 psi. Upon tripping the PSL, the SSV tripped and held DP but the SSSV stayed pressured up. The SSSV was found to be blocked in at the panel needle valve. The AOGCC inspector was notified and then the panel was normaled and the SVS system retested successfully. What Went Wrong: SSSV needle valve was left blocked in or inadvertently blocked after well was released from Slickline. The blocked in needle valve resulted in SSSV being improperly defeated at the panel with the well online for 4-5 hrs, without a tag as required by 20 AAC 25.265. Corrective Action: When a well is released following well work, an SVS function test should ` be performed to confirm that the SVS is � � i 4 c operational. The function test verifies that a trip ', �� fi of the lowpressurepilot initiates valve closure. It - ,"fir is important to distinguish this "function" test Li 0, from a State witnessed "performance" test which is done after the well is online and includes 200 psi differential pressure testing of individual SVS ,..1 valves. 14 ' ' ' ., At Endicott, following well work, the "Hilcorp Well Release Form" will be filled out by the operator g and filed with the lead operator. The form includes a function test. Additionally, Endicott SVSr -, „zoo*j test procedures have been modified to include a ' ✓ „1:',,,*`: confirmation confirmation of function test prior to the performance test if the well had work done. Figure 1:SSSV Defeated at Panel • S •V Z 0 0 0 0 t3 cu zzzz k C.) 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LL �-- ollQ ��II I II d" yam., Q11111 Ill R R •11:111111 Q U- v v) D -, a v a .) m v II cuill ' a;) > Rci aR u hoUa) = o do o ,� o o 0 + �,, N co ao1 ,... N • N 4-- v) N 'N I r� 1 g � ' •N cac O III1IIEII.y 111EP III El= co > "O ,i_ a - a a �l_ a a a �. a 4) '"" N ,� W N N N N Wi 0 , L - .yam `• L L .!l � 'r{�' Vw' L QJ a) SAV ti-) .i(1to a) a) f VV a) a) �Y a) CI a o M o 0 0 NNa r, Q. Q fl_ _ ID 2 y.v- Rpv C1. - Qr+ a' T' a _ a f' a ara a) O ai + a �+ • a) m v v �� a CO cl. o r O O Y O tNiv O {J A r,") h-1_' , O ' . •Vw\ 0 41 I A +� a a o n o V i V " E- **3 a a a ... a tr) yt a +,'1 aa. .. 0) L L I+ L I L W 1-. V • ,` L ♦ r'1 L rye L r,, a1 cr a)N ^ tru "6 a) A a o a T c to �i ro t4 Q Z O Z O Z c Z G1 Z a Z o Z A z E ho (1) v ra o a) 0 N ) 4,1 „,„) q z.....: _.Ln 4,.,„ , 1,- j E -,F, -4- $ -,3 ‹ ,... - zte 1 t ,,,11_ 1 4 -I) : z ,v,\,, v., iv 11 5 as _-' Y a) lil 41 � `B111 CI c3 (� �" ,,, , IA c ci ° k . ,•' ...i 01 p y m m 1k ra ra ra I a <a co L ca "„ a a Q: a a a; a a; a a 0 a a) a) a) ar v E a; E o_ E a � " ui ai ai N Q) �' a) �- a) � v � a) -n E a' E Q E a: E a v E n v w v m af)) CI C) H 0 I 0 F. o. j- 0 0 - O 0 }- 0 F- 0 j— 0 F- P 0 .__t SEP 19 2016 AOGCC Incident Description Well Flowing - SSSV Removed/Untagged Event Date: 12 Sep 2016 Hilcorp Alaska, LLC Location: END 2-56A, Endicott Description: SSSV was pulled on 5/24/16 from END 2-56A in support of a bottom hole pressure survey conducted during the Endicott TAR. The SSSV was not immediately reinstalled due to a lack of redressed valves. Well's wing was tagged as "Needs SVS Test" but SSSV was not flagged/tagged at panel. A note to "State test @ POP" was also left on the state test tracking whiteboard. Well was POP'd on 9/9/16 and an AOGCC SVS performance test was scheduled. The witnessed waived test was performed on 9/12/16. SSV tested good and then tubing pressure was bled down. Tubing did not pressure up indicating a passing SSSV which was recorded on the SVS test form. The operator then attempted to open the SSSV but could not pressure back up suggesting loss of control line integrity. Well was left shut-in and on 9/14/16 operations determined that SSSV had not been reinstalled and that what appeared to be a passing test previously was the well dying. What Went Wrong: SSSV was removed but no tag or flagging was left on the panel. Well was returned to production without either a function test or a tag on the panel for the removed SSSV with the information required by 20 AAC 25.265.m (See Figure 1 for Example Tag Information). Well was / AOGCC tested without an SSSV in the hole. Dying well was misinterpreted as a passing SSSV test and submitted to OUT O F SERVICE state as such. Findings/checklist from failure three weeks prior had not yet been fully rolled out. Defeated Equipment/SVS: (-1 sty Q Detection Device Q SSSV Corrective Action: As with previous failures on END 3-09A Other: and NS-15, an SVS function test, and the subsequent Reason Out of Service: attempts to "open" the missing SSSV would have revealed the missing valve prior to bringing on the well and state testing it. Because END 2-56A was handed over in May, the "Hilcorp Well Release Form" was not yet in use at the time. Going forward the release form will be used on every well handover and will be used to check the –35 wells that were worked on over the Endicott TAR to ensure there Date: were no other handover gaps. Additionally, Northstar and Name: Milne Point are instituting processes for ensuring SVS functionality following defeat for wellwork. Figure 1: Example of tag information required for defeated/removed SVS components 0 0 L. • / o tz / 3 .0 ° \ % L / G_ Cb \ } - w _ : 2 cA E-, z \ / 0.1 0 a c - \ 1-1 Mo 3 ` t / \ ( \ a 2 \� E \ \/ Q 0 = au0 d \ k ,4....,, v 2 0 7, 1 / , 7 % $ % / 2 _ / } - / E © § 2 _ % © a � q ¢ oQ © ® u / R z 0 \ 1 cc Cat E / Z k 0.4 \ \ \ \ _ % ) \ » » ° 2 tt _\11 ; CI) Cl.) •e % % Q © 2 '§ % \ \ _ .. 2 & 4 g 7 a : & % a ® t Q - _ 6 7 a © k J - \ \ (. up \ pa B\ 7 S i t ± •\ k 2 & § •( / C4, , $ .. .6. & 0 _ / / / k 4 \ c & % U � � § _/ 2 ƒ \ 4:4 Ao \ \ c « / _ / E & \ / / / 2 / • • \ ocn 3 ril \ 0-4 \ t \ § » ® \ \ / # _ z 0 \ ƒ co) / Z _ / \ � � � k. o ks _ / / a \ % \\ ■ 2 a& a y % / / Q / • 5 \j3 / \ / ) 2 C. . \ _ et „dcw bb bA /\ ¥ z S 0.i .a k \} \ 0.ƒ CA 2\ • 0 )II _/ % % e x q ¢/\ R z 0 5 6 � z k � � � \ 4 x CU _ \ -cs # % a.; \ • t o a z d \ \ / i L. 0 _ _ Q. n a 2 7 Cr) 7 a : kr) / 0 } / •§ 3 , \ K \ / \ � \ } � { � / k 4 o 0 k � a 0 • \ / \ \ '\ / ¥ y z \ i,,', & & _ 6 y _ ) / / 7 G . 2 U a e a o ) L ¢ / 6 / o \ ` — = 2 \ \ § ƒ z © / A HifORP WELL RELEASE FORo Location: Well#: Date: Company: Operation: Contact Info: Personnel: Brief Job Discription: PRE SITE INSPECTION: Location Clean: SIMOPS: Well On Line: Visible Spills: Well House Condition: Well Cellar Clean: SVS System On Line: POST SITE INSPECTION: Location Clean: SIMOPS: Well On Line: Visible Spills: Well House Condition: Well Cellar Clean: Roof Doors Closed: Safety System Check List: SVS Panel Operational: Master Valve Open: Main Supply& Return Valves Open: Swab Valve Closed: SSSV Supply Open: Tree Cap Installed &Tested: SSSV Vent Closed: SSSV Tree Control Open &Zip Tied: SSV Supply Open: SSSV Tree Balance Open &Zip Tied: SSV Vent Closed: IA Gate Valve Open: SSV Three Valve Lined Up To Panel: IA Gauge Valve Open: Of V° SSV Fusable Removed: OA Gate Valve Open: QeC *y. 19 2p1b PSL Switch In Normal: OA Gauge Valve Open: SSP p.,OGGO PSL ROOT Valve Open: OOA Gate Valve Open: SSSV Installed and Pretested: OOA Gauge Valve Open: SVS Pre-Test Function Complete: All Bleeds Closed: REMARKS: Operations Signature: Date: E-PAD SHIFT LOG 9/16/2012 Day 41ator:Vallely Night Operator: Per ESP PRODUCTION Safety .WELL CK/HT DT/HR FBHP HZ AMPS FTP I/A O/A Temp Supported TARGET System By TARGET 4 E-04 SIN 792 57 54 183 B-05,420,B 800 4 E-06 SIN 1228 50 44 188 E-07 1200 J E-08 SN 24 B-05 700 4 E-09 SIN 1135 59 56 184 E-05,E-23 1100 J E-10 S/N 24 _ B-05 1300 E-11 S/N 955 57 41 191 E-05,E-23 900 4 E-14 S/N 24 E-07 800 BEGET 4E-15 SN 24 N/A E-13B 700 f® J E-18 SN 1541 62 21 185 B-25 700 SEP 19 2016 E-19 WY 814 51 15 185 E-20 800 w 4 E-20 SIN 24 E-13SS 1150 GC J E-22 S/N 1464 48 39 214 E-05,E-23 1200 E-32 S/N 1098 45 28 206 E-12 1000 Safety Well CK/HT DTI HR PF Rate ,Pump IN PSI Pump DIS PSI FTP I/A 0/A Flowing Temp PF Target . Supported System By `i E-24A S/N 2571 1299 2048 201 2573 2450 BWPD E-29,S-01SS 300 BWPD/ \I E-31 SIN 422 1365 1806 189 2721 2000 psi B-02,B-27SS INJECTION sarety WELL cnoke/ DT/HR RATE FTP I/A 0/A TEMP Supports Target REMARKS System String BWPD/PSI E-02i S 24 XXXX XXXX <4.0 E-03i S 8029 3370 8-04,B-03 MMCF/D J E-05i W 1223 2018 E-09,11,22 1400/4470 4 E-07i S 2558 2347 E-14,E-07 3000/3000 4 E-12i S 276 1073 E-31,E-32 250/1300 E-13Ai S/SS 24 E-20 000/1100 E-13Bi S/LS 24 C-41 500/1250 4 _E-16i W 24 B-06.B-09 XXXX E-17i S 3804 2551 K-02,K-05 4700/3000 J E-23i W 2752 1839 E-09,11,22 2800/3500 J E-25 S 24 N/A E-20 XXXX E-26i S 956 1855 E-19,B-22 1000/3500 4 E-29i S 467 917 E-24 500/1250 LTSI f Safety WELL# IIA 0/A sarery WELL# I/A O I A safety system WELL# I/A OI A safety WELL# I/A 0/A system system system J E-21 0 N/A J E-28 200 60 yI E-30 40 N/A E-33 0 N/A PRODUCTION HEATERS Safety Equipment Run SID Hours REASON FOR UNIT BEING DOWN System Hours J H-4510A 24 11 H-45-10B 24 Visual storm water run-off,prod/source WI lines and ADEC 3-phase pipeline inspections by: This includes environmental pad check,visual inspection of well house cellar condition,safety systems valve alignment and check of all piping and tubing for leaks,inspection of berms on pad,daily checks of all overland flowlines that are visable from MPU roads Air volume tank blown down? TIOs entered? Time: Comments: Bot. Left: EB Well Work Safety System Bypass(WSDP,Pilot,SSV,SSSV): Bot.Center:EB WELL# REASON: PETURN'WELL TO NORMAL: SVS FUNCTION TEST COMPLETED: Bot.Right: EB WELL# REASON: TURN WELL TO NORMAL: SVS FUNCTION TEST COMPLETED: Top Left: SI 1/EI I# REASON: URN WELL TO NORMAL.: SVS FUNCTION TEST COMM ETED- Top Right: EB Document Title: Oduction Well Turnover Following 3rd Partictivity - Document Number: NSI-NP-4100 Revision Date: 09/01/2016 Document Type: Security Classification: 4 Version: 2.1 Normal Procedure Company Confidential Authority: Foreman Custodian: Operations Lead Tech Document Administrator: Document Controls Scope: Production Turnover Issuing Group: Operations Next Review Date: 04/28/2018 SEP 92816 1.0 Purpose/Scope AOG CC This procedure describes the steps necessary to ensure the well has been left in a safe condition following turnover from a 3rd party and is ready for operations to assume control and monitoring of the well for safe operation and regulatory compliance. As it pertains to this procedure, 3rd party activity is defined as anytime the control of the well is transferred from operations to another entity that may include but is not limited to drilling, wireline, well services, well integrity group, valve crew, grease crew, corrosion group, wellhead vendor, island maintenance, heavy equipment crew, subsidence crew, etc.,. Additionally, 3rd party activity is defined as anytime a person or group of persons works on or operates any component of the well or wellhead system when they are not under continuous visual supervision of the area operator. Mechanical Integrity Testing (MIT) requires the annulus to be liquid packed and pressured up. Following an MIT the annulus pressure is bled down but the annulus remains liquid packed. A liquid packed annulus poses an imminent hazard during a well start up due to thermal expansion of the liquid in the annulus. Intensive local and remote pressure monitoring and a means to bleed annulus pressure are required prior to well start-up. Bleeding of various well gases and fluids occurs on a regular basis during well integrity work. Bleeding of annular fluids to a tank is typically used when the wellbore or annulus must be bled below common line pressure. Bleeding of well pressures to a flowline is the preferred method for safety and environmental reasons. A bleed tank is only to be used when bleeding to the production system is not an option. Return all wellhead valves to their normal positions. If a piping component or valve has been removed and replaced a Pre-Startup Safety Review (PSSR) is required prior to well start-up in addition to this procedure. If the well is to be placed into production, NP-2000 Production Well Normal Startup after TA or ESD shall be used, in addition to this procedure. If work was done from the Master Valve downhole all workers must be SEMS trained and JSA must be conducted prior to beginning work. Document Number: NSI-NP-4100 Page 1 of 8 PAPER COPIES ARE UNCONTROLLED.THIS COPY ONLY VALID AT THE TIME OF PRINTING. Print Date:9/16/2016 The controlled version of this document can be found in http://filetrail.hilcorp.com/FileTrail/ Document Title: auction Well Turnover Following 3rd Party ivity Document Number: NSI-NP-4100 Revision Date: 09/01/2016II Document Type: Security Classification: Version: 2.1 Normal Procedure Company Confidential 2.0 Acronyms/Definitions TA Turnaround ESD Emergency Shutdown SDS Safety Data System 3.0 Specific Requirements 3.1 Environmental, Health & Safety Concerns 3.1.1 Environmental Concerns • Follow all company policies, environmental procedures and the "North Slope Environmental Field Handbook". • Use only high-pressure fittings & hoses to bleed pressure from annulus valves. Hoses and fittings must be inspected carefully prior to each use. Hoses with blistering, weather-checking, exposed wire or cloth braid, worn fittings or any other evidence of conditions that may make the hose unsafe must be cut up and discarded. • Always use spill containment materials when bleeding well flowlines. 3.1.2 Health Concerns • Personnel performing these duties shall be familiar with the SDS pertaining to Northstar chemicals. The SDS must be referenced for its properties, hazards, PPE required and the control measures to be taken if physical contact occurs. • For this procedure special consideration should be given to the following: Natural Gas, Crude Oil, Diesel. • See SDS for detailed information and necessary personal protection equipment. The process stream may contain H2S, Benzene or small amounts of process chemicals; however, exposure to a technician performing these activities is not anticipated. 3.1.3 Safety Concerns • Safe work practices in accordance with company policies, procedures and the Alaska Safety Handbook (ASH), are to be understood and followed during the execution of this procedure • High Pressure Document Number: NSI-NP-4100 Page 2 of 8 PAPER COPIES ARE UNCONTROLLED.THIS COPY ONLY VALID AT THE TIME OF PRINTING. Print Date:9/16/2016 The controlled version of this document can be found in http://filetrail.hilcorp.com/FileTrail/ Document Title: auction Well Turnover Following 3rd Part ctivity Document Number: NSI-NP-4100 Revision Date: 09/01/2016 Document Type: Security Classification: Version: 2.1 Normal Procedure Company Confidential 3.2 Pre-requisites • All system work permits have been returned to the control room. • All system master cards are closed out 3.3 Equipment, Materials, Tools 3.3.1 Equipment • None unique to this procedure 3.3.2 Materials • None unique to this procedure 3.3.3 Tools • None unique to this procedure 4.0 Key Responsibilities 4.1 Area Operator 4.1.1 Verify valve position checklist is complete. 4.2 Control Room Operator 4.2.1 Notify the Foreman that well is in production. 4.3 Safety Advisor 4.3.1 Determine need for Confined Space Entry Permit Procedure Begins on Next Page Document Number: NSI-NP-4100 Page 3 of 8 PAPER COPIES ARE UNCONTROLLED.THIS COPY ONLY VALID AT THE TIME OF PRINTING. Print Date:9/16/2016 The controlled version of this document can be found in http://filetrail.hilcorp.com/FileTrail/ II Document Title: action Well Turnover Following 3rd Part ivity Document Number: NSI-NP-4100 Revision Date: 09/01/2016 Document Type: Security Classification: Version: 2.1 Normal Procedure Company Confidential 5M Pr.c-dure/Process I Step Action Signoff 1. Safety Checks 1.1 Ensure that all planned work on the well in question is following 3rd completed and 3rd party workers are no longer Party Activity operating well components. and Turnover 1.2 If the well house is installed, verify the lighting and heat to Operations tracing is working. 1.3 Check the well and cellar area for environmental conditions. Report any findings of non-compliance immediately to the Foreman. 1.4 Check the cellar grating to ensure a safe condition. I Working below the grating of the cellar floor constitutes a confined space entry. Consult with the Safety Advisor and the Alaska Safety Handbook for requirements. 1.5 Perform the valve positioning checklist for wells that is attached to this procedure. See Appendix A. 1.6 Flag, tag and note any purposeful valve misalignment on the valve positioning checklist. Communicate the misalignment in shift notes and at shift change. Defeated safety devices are to be logged in the control room. 1.7 Verify the working condition of pressure transmitters with the control room via radio communication. 1.8 Verify the SSSV, SSV and Wing Valve actuates by the open and close buttons at the Well Control Panel and Control room. 2. Post MIT 2.1 Rig up a bleed hose from the annulus to a bleed trailer. Precautions and 2.2 Bleed a sufficient volume from the annulus to ensure Preparation correct valve alignment and pressure gauge and transmitter function and accuracy. 2.3 Verify with the control room that the pressure transmitter is operational and that the alarm points are set and active. Document Number: NSI-NP-4100 Page 4 of 8 PAPER COPIES ARE UNCONTROLLED.THIS COPY ONLY VALID AT THE TIME OF PRINTING. Print Date:9/16/2016 The controlled version of this document can be found in http://filetrail.hilcoro.com/FileTrail/ - Document Title: •uction Well Turnover Following 3rd PartOtivity Document Number: NSI-NP-4100 Revision Date: 09/01/2016 Document Type: Security Classification: Version: 2.1 Normal Procedure Company Confidential ttention! Annulus pressure(s) increase with increased flow or with fluid composition changes. Always keep this in mind when adjusting well flow or changing the service of a well. Take appropriate ��aurio�v` g� g precautionary measures to prevent a pressure excursion incident. 2.4 When the well is placed into service, be prepared to monitor and bleed the well continuously until thermal stabilization has occurred. 3. Records 3.1 Sign off this procedure below and hand in to the Lead Tech. END OF PROCEDURE Technician Signature Date of Completion Supervisor Signature Date of Completion 6.0 Key Documents/Tools/References • PI-S3-ME-0052 sh1 HP Production Wells • PI-S3-ME-0054 sh1 Wells Manifold C Procedures NP-2000/3000/9000 and EP-0300 for production wells • Procedures NP-2015/3015 for well hydraulic ESD system c Valve Positioning Checklist for Wells is located in Appendix A. 7.0 Comments Document Number: NSI-NP-4100 Page 5 of 8 PAPER COPIES ARE UNCONTROLLED.THIS COPY ONLY VALID AT THE TIME OF PRINTING. Print Date:9/16/2016 The controlled version of this document can be found in http://filetrail.hilcorp.com/FileTrail/ IIDocument Title:ber:Suction Well Turnover Following 3rd Parttivity Document NumNSI-NP-4100 Revision Date: 09/01/2016 Document Type: Security Classification: Version: 2.1 Normal Procedure Company Confidential Revision/Review Log Annual Date Custodian Review Authority/ Revision Details MOC No. Y/N Approval 08/01/2013 J Croak J Sharp Version 1 —Latest revision received 0404 M Johns J Johnson from BP 03/07/2015 L Kulhavy H Mann Added step to check heat trace and function test SSV and SDV push buttons, removed BP logos references etc 04/28/2015 W Rivard J Stale y Version 2—Convert to Hilcorp: B Bryant y Added 8 checklist items to Appendix A to verify positons of supply/return lines for the SVS hydraulic system 09/01/2016 Bill BryantN Lance Kulhavy 2.1 —Modify step 1.8; added line HAK31-08- items to Appendix A checklist 2016_446 Document Number: NSI-NP-4100 Page 6 of 8 PAPER COPIES ARE UNCONTROLLED.THIS COPY ONLY VALID AT THE TIME OF PRINTING. Print Date:9/16/2016 The controlled version of this document can be found in http://filetrail.hilcorp.com/FileTrail/ Document Title:•duction Well Turnover Following 3rd Parctivity Document Number: NSI-NP-4100 Revision Date: 09/01/2016 Document Type: Security Classification: Version: 2.1 Normal Procedure Company Confidential Appendix A: VALVE POSITIONING CHECKLIST FOR WELLS All valves to be checked off prior to initial start up and after wireline work. Well Number: Date: Reason for performing check: Valve Position Initials/Date IA 2"lower casing valve Open IA 2"upper casing valve (if there is one) Open IA PT needle valve Open IA PI needle valve Open IA bleed needle valves Closed IA bleed plugs are in place Yes OA 2" lower casing valve Open OA 2"upper casing valve (if there is one) Open OA PT needle valve Open OA PI needle valve Open OA bleed needle valves Closed OA bleed plugs in place Yes Alternate IA Casing valve Closed Alternate IA needle valve Closed Alternate IA plug is in place Yes Master Valve Open Companion Valve Closed Companion bleed needle valve Closed Companion bleed plug is in place Yes Swab valve Closed Swab cap On Tree cap pressure indicator needle valve Open Tree cap bleed plug is in place Yes Manual wing valve on injector Open Choke Closed Flowline PT needle valve Open Flowline PT bleed valve Closed Flowline PT plug is in place Yes Flowline PT root valve Open Flowline PI needle valve Open Flowline PI bleed valve Closed Flowline PI plug is in place Yes Flowline PI root valve Open Flowline highpoint bleed are all valves closed and plugs in Yes place Document Number: NSI-NP-4100 Page 7 of 8 PAPER COPIES ARE UNCONTROLLED.THIS COPY ONLY VALID AT THE TIME OF PRINTING. Print Date:9/16/2016 The controlled version of this document can be found in htto://filetrail.hilcorp.com/FileTrail/ liDocument Title: •uction Well Turnover Following 3rd Partlitivity Document Number: NSI-NP-4100 Revision Date: 09/01/2016 Document Type: Security Classification: Version: 2.1 Normal Procedure Company Confidential Is well lined up to the correct header? (producer) Yes Is bleed valve closed and all plugs in place (injector) Yes Are both header valves open (injectors) Yes Hydraulic Supply for Wing Valve Open Hydraulic Return for Wing valve Open Hydraulic Supply for Surface Safety Valve Open Hydraulic Return for Surface Safety Valve Open Hydraulic Supply for Sub Surface Safety Valve Open Hydraulic Return for Sub Surface Safety Valve Open Hydraulic Supply for PSV Open Hydraulic Return for PSV Open Function Test SSSV from the Control Room& Well Control Panel Function Test SSV from the Control Room& Well Control Panel Function Test Wing Valve from Control Room & Well Control Panel Comments/Deviations: (continue at end of next page if necessary) Document Number: NSI-NP-4100 Page 8 of 8 PAPER COPIES ARE UNCONTROLLED.THIS COPY ONLY VALID AT THE TIME OF PRINTING. Print Date:9/16/2016 The controlled version of this document can be found in http://filetrail.hilcorp.com/FileTrail/ • • Regg, James B (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> �,n ,� 0115 1 Sent: Thursday, September 15, 2016 3:37 PM l�G!� To: Regg,James B (DOA) Subject: Defeated/Removed SSSVs at Endicott Prior to AOGCC SVS Tests Jim, Hilcorp has experienced two recent failures to properly identify defeated/removed SVS components from wells at our Endicott field. If possible, I would like to setup a meeting on Monday morning (9/19/16)to go over the details of these incidents and the corrective actions we intend to put in place. Here is a summary of the two incidents: END 3-09A: Defeated SSSV Supply Valve At Panel Following Wellwork (P-r15 I9501cio' END 3-09A's SSSV was pulled on 8/15/16 in support of a pressure survey and was reinstalled with Slickline on 8-26-16. The well was brought online at 9am and SVS performance tested at 2 pm.The performance test was witnessed by the AOGCC inspector already onsite to witness an MIT and other SVS tests. Upon tripping the low pressure pilot,the SSV tripped and held differential pressure but the SSSV stayed pressured up.The SSSV was found to be blocked in at the panel needle valve.The AOGCC inspector was notified and then the panel was normaled and the SVS system retested successfully. Defeated valve noted on SVS test form.The well is currently on production. END 2-56A:SSSV Removed But Not Recognized/Tagged Following Wellwork: C Q7i) l`t005-b0 END 2-56A's SSSV pulled on 5/24/16 in support of a pressure survey but could not be reinstalled immediately due to valve availability. Well was left shut in and tagged for needing SVS test but tag did not mention SSSV. Well was put on production on 9/9/16 but it was not recognized that the SSSV had been removed.AOGCC performance test was scheduled.The witnessed waived test was performed on 9/12/16. SSV tested good and then pressure was bled down above SSSV.There was no pressurization indicating a passing SSSV which was ultimately recorded on the SVS test form. The operator then attempted to open the SSSV but could not pressure back up suggesting loss of control line integrity. Well was left shut-in and on 9/14/16 operations determined that SSSV had not been reinstalled and that what appeared to be a passing test was the well dying. The well remains SI. Corrective Actions: • Well handovers following wellwork will include a function test of the SVS to ensure all valves are properly configured and nothing is inadvertently removed/defeated. • Function tests to be tracked as part of a Hilcorp Well Release Form that is submitted to the Lead Operator after every handover.This Well Release Form was generated following the END 3-09A failure but had not been in use at the time of the END 2-56A well handover on 5/25/16. Use of the release form is now mandatory following all wellwork and will be fully rolled out to all Endicott well operators by the end of the month. • A higher than average volume of wellwork was conducted prior to and during the August Endicott turnaround. The Well Release Form will be used on all wells with work done during or in preparation for the turnaround to verify there were no other gaps in wellwork handovers. • Northstar and Milne Point fields were notified of the defeated valve on 8/31/16. Field specific procedures will be modified to ensure a function test is performed following wellwork to verify the SVS system. Please let me know if Monday morning will work for you or if there is any additional information I can provide now. Hilcorp attendees would be myself and the Endicott/Northstar Operations Manager, Mike Dunn. Thank You, Wyatt Rivard I ‘11‘11 Cr i e =141; 1 • 0: (JO!) C: ':,1)9)t.,/(i-!1003 I wrivard@hilcorp.com 380()cemerpointlve,Mlit? "1401.) /0<99.503 II V1.1.1“4, .1 2 OF Ili Ce I1/7; THE STATE Alaska Oil .,nd Gas OALASKA Conservation Cornmission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov September 14, 2016 CERTIFIED MAIL— RETURN RECEIPT REQUESTED 7015 1660 0000 1487 7142 Mr. Mike Dunn Endicott Operations Manager Hilcorp Alaska LLC P.O. Box 244027 Anchorage, AK 99524-4027 Re: Docket Number: OTH-16-024 Notice of Violation Defeated Safety Valve System Duck Island Unit 3-09A(PTD 1950190) Dear Mr. Dunn: On August 26, 2016 an Alaska Oil and Gas Conservation Commission (AOGCC) Inspector witnessed the well safety valve system tests on Endicott Satellite Drilling Island within the Duck Island Unit pad that were performed by a Hilcorp Alaska LLC (Hilcorp) representative. The safety valve system on well 3-09A was found defeated. Investigation revealed that a valve at the control panel was closed preventing actuation of the subsurface safety valve. The subsurface safety valve did pass the required performance test once the valve was normalized. A copy of the Inspector's report is attached. The facts reported by the AOGCC Inspector indicate a failure to maintain an operable safety valve system which is a violation of State regulations. Hilcorp is reminded that a producing well must be equipped with a functional safety valve system as described in 20 AAC 25.265: - Paragraph (h)(2)requires a performance test following installation, repair, or replacement of a subsurface safety valve; - Paragraph (j)(1) allows the subsurface safety valve to be removed for a tubing workover, well intervention, or routine pad or platform operation. The subsurface safety valve must be tested within five days after installation; - Paragraph (m) establishes tagging procedures for a well safety valve system component that is inoperable, removed, or blocked. There was neither a tag observed on Endicott 3-09A that would indicate an inoperable safety system nor was there any reason for the valve to be defeated. Defeating any component of the critical well safety valve system—except as provided in 20 AAC 25.265 —will not be tolerated. • Docket Number:OTH-16-024 Notice of Violation—Endicott 3-09A September 14,2016 Page 2 of 2 Within 14 days of receipt of this letter, you are requested to provide the AOGCC with a written explanation of how this event happened, identify when it happened, and describe what has or will be done in the future to prevent its recurrence at Hilcorp-operated fields in Alaska. Failure to comply with this request will be an additional violation. The AOGCC reserves the right to pursue enforcement action in connection with the defeated safety valve system on Endicott 3-09A. Questions regarding this letter should be directed to Jim Regg at 907-793-1236. Sincerely, Orio, Cathy '. Foerster Chair, Commissioner Attachment cc: P. Brooks AOGCC Inspectors RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or decision,or such further time as the forgood cause shown, aperson affected byit mayfile with the AOGCC an application for reconsideration of the AOGCC grants matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must respect in which the order set out the or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction,in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather,the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. t • • to '" c w n. ice. 0 c.r w c CJ ...', c` -0 R i a C Z U V C.� G '' p E. O 2 M 1:4w � .� rt -z (I) c. w H G ' 00 V ct r, ar =� G. V e I. .. a 0 T_ 0 o 0 0 G f...4 �Q r; z z z z s. O/ a N �_ ta Ljf U y .i." J U '.J w :// O Z1 a >" i y )"' y C r1 4— 9 0 .r CA , r.. L ✓. C x 1+ x [�� N un . . - Cn, rI N O E G ^ u co) a L. y R r ,-- x N N O Cci L. Y~ ^ f :{ ;.: N � a C/1 G C. P D.•- M P V — V/ _ CC' v).••••••43 f (1) a o � TL.LI) 04 _ Y 2 o � � r V ....1 C#) .. li J n r-01 V X Ct 0cez _ Ca Ct117 J L ... 'V 4.k ,u v - L ^,.. L`. 'Cr" OC G. a. 0. 0 "'!'1 'C .. c x x x �.�t (-) Ci `v x r•- V1 A 0 V C. a c ., w N NN '/ N O. C C O C'. L C rn, r O E E c r- rl o _U u 9 F. r N P O x f Q Qr. y 3 ' c u co z __ ¢ E `_ ¢ Z u E 0 0, O Y, u > ^v j M f%, v E T7 0ro • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg \/eqq '1(61 DATE: 8/26/16 P. I. Supervisor FROM: Matt Herrera SUBJECT: Defeated SVS Petroleum Inspector Duck Island Unit 3-09A PTD 1950190 Endicott SDI Hilcorp Alaska LLC On 8/26/16 I traveled out to Hilcorp's Endicott Facility to witness a Mechanical Integrity Test on a well and several miscellaneous Safety Valve System (SVS) tests. Upon beginning the SVS test for Endicott well 3-09A we encountered the subsurface safety valve (SSSV) was "Defeated" on the wellhead shutdown panel. The valve that allows for pressurized hydraulic fluid from the panel to the valve had inadvertently been left closed. The SSSV would NOT have operated in the event the well encountered a "low pressure" situation; the low pressure pilot on this well was set at 190psi which was in compliance with requirements. After documenting infraction and discussing how to prevent future occurrences we tested the well components and all passed without issue. Attachments: None Non-Confidential 2016-0826 SVS Endicott_3-09A Defeated mh.docx 1 ofl U.S. Postal Servicer" CERTIFIED MAIL® RECEII' f • rU Domestic Mail Only ra For delivery information,visit our website at www.usps.com'°. N P Certified Mail Fee cr.1 i'- $ r. Extra Services&Fees(check box,add fee as appropriate) ❑Return Receipt(hardcopy) $ O 0 Return Receipt(electronic) $ Postmark Q ❑Certified Mail Restricted Delivery $ Here C3 ❑Adult Signature Required $_ 0 0 Adult Signature Restricted Delivery$ Postage O ..D $ ..D Total Postage and Fees $ Mr. Mike Dunn Sent To — Endicott Operations Manager rq Street and Apt.No.,or PO Box No. HIICOrp Alaska, LLC - C:1 P.O. Box 244027 n- City,stare,zIP+a� Anchorage,AK 99524-4027 PS Form 3800,April 2015,s^d 75,-- ..-...... - - :al SENDER: COMPLETE THIS SECTION COMPLETE THIS SECTION ON DELIVERY J • Complete items 1,2,and 3. A. Signatur • Print your name and address on the reverse X %P ❑Addressee so that we can return the card to you. ed b ( n • Nam®) C to of i , • Attach this card to the back the mailpiece, ) A imp,• on the front if space permits. 1 • i .a.�^�� ( D. Is delivery address different f m item 1? 0 Yes If YES,enter delivery addr s below: ❑ No Mr a Dunn End-ioraLions Manager SSP 2 1 2016 :_Hikorp,Alasha, LLC __,P.6. Box 244027 Anchorage,AK 99524-4027 AcGC C 3. Service Type 0 Priority Mail Express® 111111111111111111111111 III II I II I I II 111111111 ❑Adult Signature 0 Registered MailTM 0 Adult Signature Restricted Delivery 0 Registered Mail Restricted [.Certified Mail® Delivery 0 Certified Mail Restricted Delivery )Return Receipt for 9590 9401 005? 5071 0129 35 0 Collect on DeliveMerchandise 0 Collect on Delivery Restricted Delivery 0 Signature Confirmation'"^ 2. Article Number(Transfer from service label) ---'sured Mail 0 Signature Confirmation 7 015 1660 0000 1487 7142 lsured Mail Restricted Delivery Restricted Delivery wer$500) PS Form 3811,April 2015 PSN 7530-02-000-9053 Domestic Return Receipt I 1 S Regg, James B (DOA) From: Herrera, Matthew F (DOA) (l7(t(e Sent: Saturday, August 27, 2016 4:41 PM l To: Regg,James B (DOA) Subject: RE: Endicott Just received email from Endicott Operations I knew one had recently had wireline replacing SSSV and it was this well. Wireline turned the well over to Operations at 0900 8/26/16. From: Regg, James B (DOA) Sent: Saturday, August 27, 2016 11:02 AM 0v .�)C.--) Z ' `or-4e- t"-`6 1, To: Herrera, Matthew F (DOA) Subject: RE: Endicott r "r replace_ SVS care-K401,- Good memo. Any idea how long this had been defeated? wt) SSSSL �ru� - .�u , tau ) (9- (bc . P4 1'P6 v), qs ► � Sent from my Samsung Galaxy smartphone. 2r „ _ t9�Q�a,1�1� I'L'rtikdLtS ark- r€k% -4z) Se%vt ce cj 5 � PCT" �cL ct Original message (Asa, From: "Herrera, Matthew F (DOA)" <matthew.herreraaalaska.gov> Date: 08/27/2016 6:44 AM (GMT-09:00) To: "Regg, James B (DOA)" <jim.regg(a,alaska.gov> Subject: Endicott Jim Yesterday while SSV testing at Endicott I encountered an SSSV blocked in on a well. I wrote up a Memo for it.The Acronyms are detailed not to insult your intelligence but in the event someone who is not familiar with these terms reads the Memo. Matthew F Herrera Petroleum Inspector Alaska Oil &Gas Conservation Commission Matthew.herrera@alaska.gov 907-659-2714 (Slope Office) 907-448-1228(Slope Cell Ph) 907-953-7966(Personal Cell Ph) 1 • • Regg, James B (DOA) RSS Feed: AOGCC Inspection Request Posted on: Wednesday, August 24, 2016 6:59 AM Author: AOGCC Inspection Request Subject: AOGCC Inspection Request - Submission (2016-08-24 06:58:32) Full article link: https://www.jotform.com/submission/347859912451809586 Submission Date : 2016-08-24 06:58:32 IP Address : 107.152.125.154 Type of Test Requested: : MIT SVS Requested Time for Inspection : 08-26-2016 2:00 PM Location : Endicott Name : Larry McBride E-mail : Imcbride@hilcorp.com Phone Number : (907) 7156950 Company : Hilcorp Alaska Other Information: : SSSV's on wells 1-47, 2-58, 2-68, 1-55 & possibly 4-10 were changed out. 1-05 gas injector IA high pressure shutdown switch changed out, and MIT-IA on water injector 3-01. Would you care to witness? View article... ,,�,�` 'n-C ccs- 3-C A- -FurneA_ tC,t g3/2b/1t„ •- 'Jo rwfi'c� 56- gayI�� Hilcorp Alaska, LLC �' ; '�k L"y: John Barn Senior Vice President ice FEB 1 9 2015 I Post Office Box 244027 t Anchorage,AK 99524-4027 AOGCCAOGCG Rcatriu,, C February 18, 2015 S.J f ,ucc& a s Commissioner Daniel T. Seamount tesvch H i lcbr(' Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 f•r(P +w€ C4 A-i Anchorage, AK 99501 - 4(4141:1 - a�u Re: Docket No. OTH-1 S 004 }� Defeated Safety Valve System _ Northstar 15 (PTD 2020540) > I Ae CPC+ CtkPreetwi a,- ± Dear Commissioner Seamount: We respond to your February 4, 2015, letter regarding the referenced matter. Description of Events NS-15 is a naturally flowing producer that had been shut-in due to a leak in the surface casing since March 28, 2009. On Jan 17, 2015, we initiated preparations to return NS-15 to production including slickline installation of the surface controlled subsurface safety valve (SCSSSV). As per SOP, the surface safety valve (SSV) hydraulic supply line was temporarily blocked during the slickline wellwork. Because of the ongoing well work activities, the valve was not required to be tagged. 20 AAC 25.265 (m). We completed the slickline wellwork on January 21, 2015. As part of the "NSI Prod Well Turnover" procedure, the well operator checked the open/closed status of SSV supply line needle valve. The valve does not give visual indication and must be manually rotated to check. The operator felt resistance in the valve handle and believed it to be open. He added an orange tie wrap to the valve. Local SOP is that valves that have an orange tie wrap are in the open position. NS-15 was brought on production and notification was made for an inspection. On January 23, 2015, the SVS system was performance tested in the presence of an AOGCC Inspector. The Inspector requested the test be done with the well flowing. The pilot was tripped and SCSSSV subsequently closed but the SSV failed to close. Further inspection of the SSV revealed that the hydraulic supply Iine was blocked in by the needle valve that was incorrectly tie wrapped to indicate an open valve. The needle valve was then opened and SSV performance tested successfully. The SCSSSV passed the performance test but, in the process of closing against the flowing well, appears to have come off-seat from nipple enough to lose control line continuity. NS-15 has remained and will continue to be left shut-in until the SCSSSV can be reset and SVS system retested. • • Commissioner Daniel T. Seamount February 18,2015 Page 2 of 2 Cause of Incident We determined that a procedural gap exacerbated by an operational oversight caused the failure of the SSV to be in position to close on NS-15. The procedural gap was the absence of a function test to verify proper operation of the SVS components after completion of well work. The operational oversight was a failure to recognize the correct valve configuration. Prevention of Future Occurrences We have undertaken the following steps to prevent future occurrences: Field wide Incident Review: We prepared and distributed an incident report of the failure at NS-15 on February 18, 2015, to field operations personnel at Northstar, Endicott and Milne Point. Turnover Procedure Modification: We found the "NSI Prod Well Turnover" procedure had no provision for a function test of SSV and SCSSSV after verifying valve position. A function test is the best way to verify that the system is returned to an operational state after turnover wellwork. We have now modified the "NSI Prod Well Turnover" to include function testing in step 1.8 as well as eight additional valve positioning checklist items to prevent re-occurrence of this in the future. Training Review: As we did for our Cook Inlet operations, we are preparing a slide deck on SVS care and operation. We will use the slide deck in a supplemental training session to reach all our North Slope operators within the next six weeks. Then we will include the SVS module in our regular training cycle. If you have any additional questions, please contact Wyatt Rivard at 777-8547 or by email at wrivard@hilcorp.com. Sincerely, HILCORP ALASKA, LLC jZ.,,.._IV r John Barnes Senior Vice President • 0 1 , [1 I -./A 4:g Ai ' ' hl ,:t ,k-h-.. '," 1 #4&,% Vkis 1 Hileorp Alaska,L.LC Event Date: 23 January 2015 Location: NS-15, Northstar Island Description: Slickline completed work on NS-15 on Jan 21, 2015. As part of the turnover,the , well operator checked the valve positions including open/closed status of SSV supply line i needle valve. The operator felt resistance in the valve handle and � � ��R,, believed it to be open. , „. Z . , „„. NS-15 was returned to production and ,F; on January 23, 2015 the SVS system _ s was performance tested in the ' „ k , presence of an AOGCC Inspector. The -- r pilot was tripped and SSSV y; ,. i'----41'4.'- .,,,,,;,..;:-.,/,,m, _- subsequently closed but the SSV failed �'- [4.1 to close. Further inspection of the SSV revealed that the hydraulic supply line was blocked in by the needle valve. NS-15 Defeated $$V 4 This constitutes an untagged, improperly defeated safety system and og is a violation of AOGCC regulation 20 . ,.., AAC 25.265. What Went Right: Operator followed "NSI Prod Well Turnover" procedure and examined the valve positions prior to returning well to production. What Went Wrong: Needle valves used to isolate safety systems do not give a visual indication of open/closed status. Every effort must be made to ensure valve is in fact open and ff not just tight. What Can Be Done to Make it Right: Once all valves are believed to be in normal operating state, a function test of the system provides final verification. "NSI Prod Well Turnover" procedure has been modified to include SSV and SSSV function test as a final check. 9. .,... ....7,2.�.�..,.:r,k ^':,"<T„'„.. ..,m>„,',,c. 21r�,,...:a=' a.: �''��.:',wx. Y s7pan 3 'WSW mac 2.' a ax.. —Vr,k • S Hilcorn Alaska, LLC Post Office Box 24'.40)7 Anchorag,>,AK 99524-4027 3800 Centerpoint Drive Suite 100 flavor') 1Ia,kai. Anchorage,AK 99503 Phone:9077777-8300 Fax: 907/777-8301 January 30, 2014 Ms. Cathy P. Foerster Chair, Commissioner Alaska Oil and Gas Conservation Commission State of Alaska 333 W. 711'Avenue, Suite 100 Anchorage, AK 99501-3539 Re: Swanson River Field (SRF), Soldotna Creek Unit(SCU) SCU 12A-04 (PTD 1740210) and SCU 41A-08 (PTD 1940850) Safety Valve Systems (SVSs) SCU 24A-09 (PTD 1750220) Outer Annulus Pressure Gauge Dear Chair and Commissioner Foerster: We respond to your letter dated January 14,2014, regarding the matters noted above. Your letter directed Hilcorp as follows: - Install an appropriate outer annulus pressure gauge on SCU 24A-09; - provide AOGCC with an explanation of how these non-compliances happened and what has been or will be done in the future to prevent recurrence at Hilcorp-operated well sites in Alaska. SCU 24A-09 Outer Annulus Pressure Gauge We are a bit puzzled by the report that SCU 24A-09 was observed to be without a pressure gauge to monitor the outer annulus. SCU 24A-09 did have and has had an outer annulus pressure gauge on it since the well was worked over in January of 2013. Hilcorp monitors and records this pressure on a daily basis. We enclose a pressure plot of this well showing the inner and outer annuli pressures for each day. We have noted that our report submitted with the SVS test did not correctly report the reading for this outer annulus at 200 psi on December 9, and we will be submitting a corrected report. Rod Pump Well SVSs Both SCU 12A-04 and SCU 41A-08 are rod pump wells. SVSs were installed on these wells at the time of the rod pump installation in March (SCU 41A-08) and July (SCU 12A-04) of 2013. Because these wells are both no-flow wells, the SVSs work by shutting down the motor to the pump,rather than closing a valve. The AOGCC witnessed (by Lou Grimaldi) the operation of the SVSs on these two wells in September. As noted in your letter, by letter dated September 24, 2013, the AOGCC approved a r • Ms.Cathy Foerster January 30,2014 Page 2 of 5 variance for all Swanson River Unit wells that are equipped with rod pumps allowing them to operate with an alternate surface safety system, requiring the use of functionally equivalent components designed for rod pump wells which will automatically terminate production. These controllers have two modes: automatic and manual. In automatic mode, the controllers sense the weight on the rod pump rod, translates that to fluid volumes, and adjusts the rate of the pump accordingly. In manual mode, the controller is set to cycle the pump a certain number of times per minute regardless of the fluid volumes. It appears when the respective manufacturers installed them, the controllers were programmed to work with the automatic mode, but were not properly programmed to operate in manual mode. The failures on the two rod pumps were two different kinds of failures, but both were programming failures on the two different types of controllers. SCU 12A-04 Rod Pump Well SVS SCU 12A-04 rod pump is a Lufkin beam style pump with a Lufkin controller. The SVS failure on this well was a programming error in the controller where the shutdown was bypassed in the Programmable Logic Controller(PLC). Hilcorp has not determined how the proper pump motor shutdown operation was disabled in the PLC programming. (To disable this feature, it requires someone with a programming background as it is not a simple switch that can be turned on or off.) A function test of this well was performed 4-days prior to the failure and the system acted properly. The PLC was reprogrammed immediately after the failure to properly turn the pump motor off on low pressure at the flow line. All Lufkin controllers have been reviewed to ensure that the proper programming is completed in the respective PLCs. SCU 41A-08 Rod Pump Well SVS SCU 41A-08 well is a Weatherford Rotoflex unit with a Weatherford controller that controls the unit and has the shutdowns programmed in this device. On December 8, 2013, Hilcorp personnel set the controller in manual mode for the first time since its installation in March of 2013. Cold temperatures had caused the wellhead to build paraffin in the tree, slowing how fast the rods ran into the well. The counter weight used on this style of pump was trying to fall faster than the rods. This situation created the risk of surface damage to the equipment. The unit was put in manual mode to slow the speed of the pump. The SVS was tested on the following day (December 9), and the controller did not trip the motor on the low pressure. This was found to be a programming error committed when the manufacturer originally set up the controller. In auto mode, the tag was enabled to shut in the unit on low pressure; however, this feature was never originally programmed for manual mode. This feature has been activated on this controller as well as the other rod pump controllers in the field,to ensure that the low pressure shutdowns work in both manual and automatic. * * * * * • • • Ms. Cathy Foerster January 30,2014 Page 3 of 5 We think it is important to note that neither SVS was "defeated" through the voluntary conduct of the operators or anyone else. The programming errors which were discovered were not created by anyone at Hilcorp or its contractors making a conscious decision to defeat the SVSs. Neither were the SVSs taken out of service during well work, and then left defeated and untagged. We have corrected the programming errors, and reviewed and revised the programming for other similar equipment. Ililcorp has developed a standard SVS regulatory awareness training curriculum that was rolled out to our field operators in December. This training includes information and operating instructions for the SVSs on the rod pump wells. As with any training program, we have completed the training module for most workers. However, there remain a few individuals who have not yet received the training. We have listed them and directed our field foremen to complete their training. If any additional information for this event/occurrence is required, please contact me and I will get more information as soon as possible. Hilcorp will continue to work diligently with AOGCC to ensure that all the well work we perform will be safe. Sincerely, HILCORP ALASKA, I,LC Chad Helgeson Operations Manager,North Kcnai Asset Team cc: Luke Saugier Attached: Photo of SCU 24A-09 Outer Annulus Pressure Gauge SCU 24A-09 Outer Annulus Pressure Gauge Readings • Regg; James B (DOA) From: Bruce Hershberger <bhershberger@hilcorp.com> Sent: Tuesday, September 10, 2013 7:28 PM To: Regg,James B (DOA) Subject: KGSF#1 Non Complince Safety Defeated Device Attachments: SSV - Actuator Photos.docx Mr. Regg On Monday September 2, 2013 Mr. Louis Grimaldi was out to witness our SRU quarterly SSV testing. During this testing KGSF#1 was found to have a needle valve in the closed position causing this safety device to be defeated, we have taken immediate action to replace this needle valve with a quarter turn valve,this valve was missed when we standardized our tubing and valves to provide a more visual approach to help our operators identify a defeated safety device. This well had been SI since spring and in July a leak in the flowline was identified and all piping at the wellhead was closed. The well was brought back into production on Friday August 30th. The SSV was tested on the 2"d The photos show the before and after valve change. We take the SSV system seriously,and we at Hilcorp continue to train and educate our people on the importance of a correctly operating system. Sincerely, Bruce Hershberger Hilcorp Production Foreman Swanson River Beaver Creek Sterling West Fork Wolf Lake West Side 1 • Hilcorp Alaska, LLC Post Office sox 244027 Anchorage,AK 99524-402/ 3800 Centerpoint Drive Iliteorp:1la.ka.L(.(, Suite 100 Anchorage,AK 99503 Phone:907/777-8300 April 25, 2013 Fax: 907/777-8301 Ms. Cathy P. Foerster Chair, Commissioner Alaska Oil and Gas Conservation Commission State of Alaska 333 W. 7th Avenue, Suite 100 Anchorage. AK 99501-3539 Re: Response to Defeated Safety System Sterling Unit 43-09X Dear Ms. Foerster: Hilcorp Alaska LLC (Ililcorp)has prepared this response to your letter dated April 11, 2013 in regards to the Sterling well 43-09X not passing the state witnessed safety valve system (SVS) test on March 15, 2013. This well was a newly acquired well from Marathon (February 1St, 2013). The well had not been on production and did not have a current SVS test (within the last 6 months)and therefore required a SVS test as required by 25 AAC 25.265. The investigation into this incident found the following results: Hilcorp was attempting to bring the Sterling 43-09X gas well onto production as it had over 1,500psi of shut-in tubing pressure and there was a need for additional gas. The well history provided by Marathon from the acquisition indicated that this well had a tendency of loading up with water and did not sustain daily production. A Hilcorp operator attempted to see if they could get sustained production from this well with management's support. When the Hilcorp operator originally tried to flow the well on March 5th, it was determined that the flowline was full of ice and the production separator needed some PLC and instrumentation work to be completed. The flowline was treated with methanol, the PLC and instrumentation work was completed and the well was capable of production on March 7th. On March 11,a Ililcorp Production Foreman contacted AOGCC about performing an SVS test to be witnessed by the state. The well was put into production and the tubing pressure bled down to the pipeline pressure (approx. 630 psi), however did not sustain any recordable production. In accordance with 20 AAC 25.265(h)(4) which allows for a new well to be put into production for 5 days before a performance test is completed following these regulations, the well was left open to production in an attempt to gain sustained production. The operator had tested the valves ability to hold pressure back prior to bringing the well onto • S Ms.Cathy Foerster April 25,2013 Page 2 of 2 production on March 7`h, however a full SVS performance test was not performed by the operator prior to production. On March 15th, the AOGCC inspector came to witness the testing of the SSV on Sterling 43-09X with a Ililcorp production operator and a contract instrument tech. As stated in your letter the inspector immediately identified upon arrival to the well that the SSV pneumatic pilot had been pinned opened(bypassed)and therefore defeating the function of the SVS. The operator released the pins attempting to take the bypass out of the system. This did not resolve the bypassed condition. The well l 4 was manually shut-in. The system had an electrical system bypass in the PLC that was not appearing as an alarm in SCADA. The SCADA technician was contacted to help troubleshoot the system. The SCADA modifications were made and the SVS was retested. The following outcomes were found during the investigation into this event. • The newly hired Ililcorp operators that worked these assets were from legacy Chevron and Marathon fields and were not familiar with the SVS testing procedures or the SVS regulations. • Marathon who previously operated this field had one individual assigned to testing the SVS and many of their operators were not familiar with all the aspects of the SVS. • We found several operators working in other onshore fields were also not familiar with the SSV regulations and testing requirements. As a results of these findings Hilcorp is preparing a SVS training that will be developed by field operators, reviewed by management and then implemented and trained to all Hilcorp operators and contract operators working the producing leases. This will initially be delivered by a field operator during the month of May. This training will also become one of the core training curriculums for all field operators. Included in this training will be a checklist of items that need to be checked prior to bringing a well onto production and leaving it unmanned,to prevent violating paragraph (m) of the SVS regulations,as well as proper identification(tags)of any defeated SVS. If any additional information for this event/occurrence is required, please contact me and I will get more information as soon as possible. Hilcorp will continue to work diligently with AOGCC to ensure that all the well work we perform will be safe. Sincerely, HILCORP ALASKA, LLC 17\a/tAi V4I-C t ' 4b-t Luke Sau er Asset Team Leader, North Kenai Team • S Post Office Box 244027 Anchorage,AK 99524-4027 Hilcorp Alaska,LLC JUL 3 0 201 ? 3800 Centerpoint Drive Suite 100 "'GCC Anchorage,AK 99503 Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 Commissioner Cathy Foerster Alaska Oil & Gas Conservation Commission 5-i Q 333 West 7th Avenue, Suite 100 6 r Anchorage, AK 99501 r ©q(IA 3- Re: Duck Island Unit Well Renaming Request Dear Commissioner Foerster, Hilcorp Alaska, LLC (HAK) requests a change to the naming convention of Duck Island Unit wells to remove the unused suffixes at the end of each well name. Well names currently include a forward slash "/" followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/121" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD# 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/T34" (PTD# 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp 9 Orig •I New I API_WeilNo I PermitNumber' WellName I WellNumber WeIlNumber 50029224180000 1931730 DUCK IS UNIT MPI 2-24/M12 2-24 50029218150000 1880550 DUCK IS UNIT MPI 2-26/N14 2-26 50029218470000 1880860 DUCK IS UNIT MPI 2-28/P19 2-28 50029218470100 2010180 DUCK IS UNIT MPI 2-28A/O19 2-28A 50029218470200 2030060 DUCK IS UNIT MPI 2-286/019 2-28B 50029222280000 1911400 DUCK IS UNIT MPI 2-30/009 2-30 50029222280100 1981880 DUCK IS UNIT MPI 2-30A/EI-02 2-30A 50029222280200 2081870 DUCK IS UNIT MPI 2-30B/ME-01 2-30B 50029220840000 1901190 DUCK IS UNIT MPI 2-32/SN3 2-32 50029216620000 1861720 DUCK IS UNIT MPI 2-34/P14 2-34 50029220140000 1900240 DUCK IS UNIT MPI 2-36/014 2-36 50029220900000 1901290 DUCK IS UNIT MPI 2-38/SN1 2-38 50029225270000 1941520 DUCK IS UNIT MPI 2-40/S22 2-40 50029218920000 1881450 DUCK IS UNIT MPI 2-42/P13 2-42 50029217670000 1871190 DUCK IS UNIT MPI 2-44/R12 2-44 50029217670100 1970710 DUCK IS UNIT MPI 2-44A/Q11 2-44A 50029219210000 1890230 DUCK IS UNIT MPI 2-46/Q15 2-46 50029219210100 1961810 DUCK IS UNIT MPI 2-46A/R10 2-46A 50029219210200 1971370 DUCK IS UNIT MPI 2-468/S13 2-46B 50029226120000 1951660 DUCK IS UNIT MPI 2-48/013 2-48 50029223670000 1930670 DUCK IS UNIT MPI 2-50/U08 2-50 50029217500000 1870920 DUCK IS UNIT MPI 2-52/514 2-52 50029222180000 1911220 DUCK IS UNIT MPI 2-54/012 2-54 50029228630000 1980240 DUCK IS UNIT MPI 2-56/EID 2-56 50029228630100 1980580 DUCK IS UNIT MPI 2-56A/EID01 2-56A 50029220410000 1900520 DUCK IS UNIT MPI 2-58/S09 2-58 50029223750000 1930830 DUCK IS UNIT MPI 2-60/U13 2-60 50029216480000 1861580 DUCK IS UNIT MPI 2-62/Q17 2-62 50029220550000 1900770 DUCK IS UNIT MPI 2-64/U10 2-64 50029220819500 1901130 DUCK IS UNIT MPI 2-66/U12XX 2-66XX 50029223740000 1930790 DUCK IS UNIT MPI 2-665D12 2-66 50029218580000 1880970 DUCK IS UNIT MPI 2-68/S17 2-68 50029218990000 1881530 DUCK IS UNIT MPI 2-70/U15 2-70 50029205180000 1801200 DUCK IS UNIT MPI 5-01/SD7 5-01 50029206400000 1811180 DUCK IS UNIT MPI 5-02/SD10 5-02 50029206390000 1811170 DUCK IS UNIT MPI 5-03/SD9 5-03 50029216780000 1861900 DUCK IS UNIT SDI 3-01/N29 3-01 50029223060000 1921210 DUCK IS UNIT SDI 3-03/J33 3-03 50029216240000 1861300 DUCK IS UNIT SDI 3-05/029 3-05 50029219110000 1890120 DUCK IS UNIT SDI 3-07/N28 3-07 50029219110100 1981470 DUCK IS UNIT SDI 3-07A/L29 3-07A 50029217800000 1880020 DUCK IS UNIT SDI 3-09/128 3-09 50029217800100 1950190 DUCK IS UNIT SDI 3-09A/128 3-09A 50029218480000 1880870 DUCK IS UNIT SDI 3-11/M30 3-11 50029217510000 1870940 DUCK IS UNIT SDI 3-15/K33 3-15 50029219460000 1890530 DUCK IS UNIT SDI 3-17/J30 3-17 50029219460100 1940460 DUCK IS UNIT SDI 3-17A/J30 3-17A 50029219460200 1971080 DUCK IS UNIT SDI 3-17B/M31 3-17B 50029219460300 1980210 DUCK IS UNIT SDI 3-17C/M31 3-17C 50029219460400 1982080 DUCK IS UNIT SDI 3-17D/M31 3-17D 50029219460500 2022470 DUCK IS UNIT SDI 3-17E/K30 3-17E PTD Loepp, Victoria T (DOA) From: Grimaldi, Louis R(DOA) Sent Thursday, March 26, 2015 8:28 PM To: Taylor Wellman Cc: Regg,James B (DOA); Loepp,Victoria T(DOA) Subject: RE: Endicott 3-09 (PTD#1950190) No Flow Testing w/SSSV open Follow Up Flag: Follow up Flag Status: Flagged Taylor I have been asked to develop a plan to assure the SSSV in subject well is open during the no-flow test. Just pressuring up the hydraulics does not guarantee that the valve is open. I am thinking along the lines of either a"check-set"tool or a pulling tool minus the "dogs". Either tool will have to have a prong of sufficient length to extend past the closure of the safety valve. This should be run immediately after the conclusion of the no-flow test. I would like to start by asking what size and type the lock and SSSV are. I should be available tomorrow to go by your W/L toolhouse to look at options. I would also think looking at a lock/sssv assembly would be helpful. Please reply with a time we can discuss this. I am on the North Slope for a few more days and would like to get tools lined out before I leave. Lou Lou Grimaldi Petroleum Inspector Alaska Oil and Gas Conservation Commission (907)776-5402(Home) SCANNED - r} (907)252-3409(Cell) Original message From: Taylor Wellman Date:03/26/2015 16:35 (GMT-09:00) To: "Loepp,Victoria T(DOA)" Cc: "Grimaldi, Louis R(DOA)" Subject: RE: Endicott 3-09 (PTD#1950190)No Flow Testing w/SSSV open Victoria, Thank you for continuing to look into this. Lou, 12 Loepp, Victoria T (DOA) From: Grimaldi, Louis R(DOA) Sent: Monday, March 30, 2015 6:38 AM To: Loepp,Victoria T(DOA) Cc: Regg,James B (DOA) Subject: RE: Endicott 3-09(PTD#1950190) No Flow Testing Follow Up Flag: Follow up Flag Status: Flagged Victoria, I stopped by and spoke with Tyrel Burley(HES), we discussed what was going on and the ultimate objective, all agreed that running a lightly pinned 4.5 GS pulling tool (w/o dogs) and a prong should serve the purpose. Said prong should be of sufficient length to ensure that the closure mechanism of the SSSV is drifted before the pulling tool engages the fishing neck of the SSSV lock. Taylor Wellman (Hilcorp) reported that the SSSV is a 4.5 HES BBE on a X lock.This should all be verified by Hilcorp and Halliburton as different configurations effect prong length. I suggest a procedure be written up and submitted, I would be glad to look it over and offer comments. One other thing to consider is that prior to the test leaving a restriction in, such as this SSSV,can change the flow profile of the well. Once removed the well may unload better and change the way it falls off when A/L is removed.The well should be tested w/o the SSSV sometime in the future to confirm. Please let me know if I could be of any further assistance, I am due back on the North Slope the evening of April 10, 2015. Lou Louis R. Grimaldi Petroleum Inspector Alaska Oil and Gas Conservation Commission 907-776-5402 (Home) 907-252-3409 (Cell) Lou.Grimaldi@Alaska.gov 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 Lou Grimaldi at 907-252-3409 or Lou.Grimaldi@Alaska.gov. From: Grimaldi, Louis R(DOA) Sent: Thursday, March 26, 2015 5:16 AM To: Loepp,Victoria T(DOA) (victoria.loepp@alaska.gov) Cc: Regg, James B(DOA) (jim.regg@alaska.gov) Subject: FW: Endicott 3-09(PTD #1950190) No Flow Testing Hi Victoria, 1 If I get time this week I can stop by the Wireline shop and see what would be needed to drift/check open the SSSV. I will need to know the style and size of the valve and lock in that profile. A well schematic would also help. Please ask them to give me a contact at the W/L shop. Louis R. Grimaldi Petroleum Inspector Alaska Oil and Gas Conservation Commission 907-776-5402 (Home) 907-252-3409 (Cell) Lou Grimaldi(a�Alaska.gov 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 Lou Grimaldi at 907-252-3409 or Lou.Grimaldi©Alaska.gov. From: Regg, James B(DOA) Sent: Wednesday, March 25, 2015 8:08 PM To: Grimaldi, Louis R(DOA) Subject: RE: Endicott 3-09 (PTD #1950190) No Flow Testing Ok. Thanks. Jim Regg Supervisor, Inspections AOGCC 907-793-1236 Sent from Samsung Mobile Original message From: "Grimaldi, Louis R(DOA)" <lou.grimaldi@alaska.gov> Date: 03/25/2015 7:43 PM(GMT-09:00) To: "Regg,James B (DOA)" <jim.regg@alaska.gov>,DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Cc: "Loepp,Victoria T(DOA)" <victoria.loepp4,alaska.gov> Subject: RE: Endicott 3-09 (PTD#1950190)No Flow Testing A pulling tool (minus the dogs) and appropriate prong can be used. I have done it on a few different style assemblies in the past. I can run by the wireline shop and see what they have if you would like. Lou Grimaldi Petroleum Inspector Alaska Oil and Gas Conservation Commission (907)776-5402(Home) (907)252-3409(Cell) 2 Original message From: "Regg,James B (DOA)" Date:03/25/2015 19:00(GMT-09:00) To: "Grimaldi, Louis R(DOA)" , DOA AOGCC Prudhoe Bay Cc: "Loepp,Victoria T(DOA)" Subject: RE: Endicott 3-09 (PTD#1950190)No Flow Testing Whatever it takes to confirm(no doubt)the SSSV is open. Jim Regg Supervisor, Inspections AOGCC 907-793-1236 Sent from Samsung Mobile Original message From: "Grimaldi, Louis R(DOA)" <lou.grimaldi@alaska.gov> Date: 03/25/2015 5:48 PM (GMT-09:00) To: "Regg,James B (DOA)" <jim.regggalaska.gov>,DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay(a�alaska.gov> Cc: "Loepp,Victoria T(DOA)" <victoria.loeppw,alaska.gov> Subject: RE: Endicott 3-09 (PTD#1950190)No Flow Testing I'm sorry but neither of their alternative methods seems positive to me. Maybe they could drift the valve with wireline. What type of valve and lock are we dealing with? Louis R. Grimaldi Petroleum Inspector Alaska Oil and Gas Conservation Commission 907-776-5402 (Home) 907-252-3409 (Cell) Lou.Grimaldi(c Alaska.gov 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 Lou Grimaldi at 907-252-3409 or Lou.Grimaldi@Alaska.gov. From: Regg, James B (DOA) Sent: Wednesday, March 25, 2015 9:28 AM To: DOA AOGCC Prudhoe Bay Subject: FW: Endicott 3-09 (PTD #1950190) No Flow Testing Heads up. 3 Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: Loepp, Victoria T(DOA) Sent: Wednesday, March 25, 2015 9:20 AM To:Taylor Wellman Subject: RE: Endicott 3-09 (PTD #1950190) No Flow Testing Taylor, The performance and validity of this no flow test will be up to the State Inspector. On the web notification form the special circumstances and request will need to be outlined in the other remarks section. Proof that the SSSV is open throughout the test will need to be demonstrated to the Inspector's satisfaction. Please be aware that the Inspector's schedule is particularly busy at this time and scheduling this test with the special circumstances may be difficult. Hope this addresses your request. Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage,AK 99501 Work (907)793-1247 Victoria Loepp analaska qov 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 Victoria Loepp at(907)793-1247 or Victoria.LoeoQ@alaska.gov From:Taylor Wellman [mailto:twellman@ hilcorp.com] Sent: Friday, March 20, 2015 3:39 PM To: Loepp,Victoria T(DOA) Subject: Endicott 3-09 (PTD #1950190) No Flow Testing Victoria, Endicott 3-09(PTD#1950190) is a gas lifted production well. We would like to pursue conducting a No Flow test on this well. In typical circumstances we would not have the SSSV installed during the time of the No Flow test. For this well 4 the wireline retrievable SSSV in the well has had a history of trouble in getting a valve to seal properly. The last SSSV used has a fully functioning valve with the aid of a swell o-ring. I would like to see if we would be able to leave the SSSV installed in the well during the No Flow test. Alternative Monitoring Methods Suggested - Upon arrival to site the inspector could watch the operator pressure up on the SSSV hydraulic line to watch the SSSV open. Conduct the normal No Flow test. - Conduct normal No Flow test. Close the SSSV and then pressure up on the SSSV hydraulic line to watch the SSSV open. Wellwork Objective: The plans for the well are to change the current GLV design in the well. To do the GLV work,the SSSV will need to be removed but I don't want to pull the SSSV without knowing that the well will not require an SSSV in the future(passing No Flow test). If you would like to discuss this further please give me a call. Thank you, Taylor Taylor Wellman Hilcorp Energy Company-Operations Engineer Office:(907)777-8449 Endicott: (907)777-8449 Cell: (907)947-9533 Email:twellman@hilcorp.com 5 Loepp, Victoria T (DOA) From: Grimaldi, Louis R(DOA) Sent: Saturday, March 28, 2015 6:22 AM To: Ryan Pitt;Tyrel Burley Cc: Taylor Wellman; Regg,James B(DOA); Loepp,Victoria T(DOA) Subject: RE: [EXTERNAL] RE: Endicott 3-09 (PTD#1950190) No Flow Testing w/SSSV open Follow Up Flag: Follow up Flag Status: Flagged Ryan/Tyrel What would be a good time today? Louis R. Grimaldi Petroleum Inspector Alaska Oil and Gas Conservation Commission 907-776-5402 (Home) 907-252-3409 (Cell) Lou.Grimaldi@Alaska.gov 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 Lou Grimaldi at 907-252-3409 or Lou.Grimaldi@Alaska.gov. From: Ryan Pitt [mailto:Ryan.Pitt@Halliburton.com] Sent: Friday, March 27, 2015 6:08 PM To: Grimaldi, Louis R(DOA);Tyrel Burley Cc: Taylor Wellman; Regg, James B(DOA); Loepp, Victoria T(DOA) Subject: Re: [EXTERNAL] RE: Endicott 3-09 (PTD #1950190) No Flow Testing w/ SSSV open That works great for us. I will be in and out tomorrow but Tyrel Burley will be in the shop all day and can assist with anything you might need. His number if you cannot get ahold of me is 907-632-3065. Ryan Pitt Service Manager Alaska Slickline Halliburton On Mar 27,2015,at 6:04 PM,Grimaldi, Louis R(DOA)<lou.grimaldi@alaska.gov>wrote: Seems like it is now in our hands up here. Ryan, I will call you tomorrow morning. If that will not work please let me know. Lou Lou Grimaldi Petroleum Inspector Alaska Oil and Gas Conservation Commission 6 (907)776-5402(I-Tome) (907)252-3409(Cell) Original message From: Taylor Wellman Date:03/27/2015 17:27 (GMT-09:00) To: "Grimaldi, Louis R(DOA)" , "'ryan.pitt(cr�halliburton.comI" Subject: FW: Endicott 3-09 (PTD#1950190)No Flow Testing w/ SSSV open Lou, After trying to come up with another solution,your idea for running the GS minus the 'dogs' is by far and away the best option. I've copied Ryan Pitt (Halliburton Slickline Lead) on this email and he will be able to have tools and someone available to take measurements of the GS and prong length to ensure the ball is open. Ryan's contact information is as follows: ryan.pitt@halliburton.com or 670-5816. Here is the record for what SSSV that is currently in the well: 4-1/2"BBE-SSSV(serial#BB4-103,60"oal,3 sets pkg,all 3 sets w/1 pc oversize ea.side of swell fix wring) Please let me know if there is anything I can do to help facilitate this or any further information needed to provide. Thanks, Taylor l a�for Wellman Hilcorp Energy Company-Operations Engineer Office: (907) 777-8449 Endicott: (907) 777-8449 Cell: (907) 947-9533 Email:twellman@hilcorp.com From: Grimaldi, Louis R(DOA) [mailto:lou.grimaldiC)alaska.gov] Sent: Thursday, March 26, 2015 8:28 PM To:Taylor Wellman Cc: Regg,James B (DOA); Loepp, Victoria T(DOA) Subject: RE: Endicott 3-09 (PTD #1950190) No Flow Testing w/ SSSV open Taylor I have been asked to develop a plan to assure the SSSV in subject well is open during the no- flow test. Just pressuring up the hydraulics does not guarantee that the valve is open. I am thinking along the lines of either a"check-set" tool or a pulling tool minus the "dogs". Either tool will have to have a prong of sufficient length to extend past the closure of the safety valve. This should be run immediately after the conclusion of the no-flow test. I would like to start by asking what size and type the lock and SSSV are. I should be available tomorrow to go by your W/L toolhouse to look at options. I would also think looking at a lock/sssv assembly would be helpful. Please reply with a time we can discuss this. I am on the North Slope for a few more days and would like to get tools lined out before I leave. Lou Lou Grimaldi Petroleum Inspector Alaska Oil and Gas Conservation Commission (907)776-5402(Home) (907)252-3409(Cell) Original message From: Taylor Wellman Date:03/26/2015 16:35 (GMT-09:00) To: "Loepp, Victoria T(DOA)" Cc: "Grimaldi, Louis R(DOA)" Subject: RE: Endicott 3-09 (PTD #1950190)No Flow Testing w/SSSV open Victoria, Thank you for continuing to look into this. Lou, Hope life is treating you well these days. When you have time, I would like to discuss the options there are for verifying the valve is open. My cell phone is listed below and I'm available whenever as I know your schedule up there can be quite hectic. Thanks, Taylor Taylor W'ellmall Hilcorp Energy Company-Operations Engineer Office: (907) 777-8449 Endicott: (907) 777-8449 Cell: (907) 947-9533 Email:twellman@hilcorp.com From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Thursday, March 26, 2015 9:37 AM To: Taylor Wellman Cc: Grimaldi, Louis R(DOA) Subject: RE: Endicott 3-09 (PTD #1950190) No Flow Testing w/ SSSV open Taylor, Lou will be in touch with you concerning this no flow test and verification that the SSSV is open during the test. I misspoke when I wrote about locking the SSSV open. 8 pro '36= Loepp, Victoria T (DOA) From: Grimaldi, Louis R(DOA) Sent: Thursday, March 26, 2015 5:16 AM To: Loepp,Victoria T(DOA) Cc: Regg,James B (DOA) Subject: FW: Endicott 3-09 (PTD#1950190) No Flow Testing Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria, If I get time this week I can stop by the Wireline shop and see what would be needed to drift/check open the SSSV. I will need to know the style and size of the valve and lock in that profile. A well schematic would also help. Please ask them to give me a contact at the W/L shop. Louis R. Grimaldi Petroleum Inspector Alaska Oil and Gas Conservation Commission 907-776-5402 (Home) SCAtINEDr�l� 907-252-3409 (Cell) Lou.Grimaldi@Alaska.gov 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 Lou Grimaldi at 907-252-3409 or Lou.Grimaldi@Alaska.gov. From: Regg, James B (DOA) Sent: Wednesday, March 25, 2015 8:08 PM To: Grimaldi, Louis R(DOA) Subject: RE: Endicott 3-09 (PTD #1950190) No Flow Testing Ok. Thanks. Jim Regg Supervisor, Inspections AOGCC 907-793-1236 Sent from Samsung Mobile Original message From: "Grimaldi, Louis R(DOA)" <lou.grimaldiAalaska.gov> Date: 03/25/2015 7:43 PM (GMT-09:00) 1 To: "Regg,James B (DOA)" <jim.regg@alaska.gov>,DOA AOGCC Prudnoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Cc: "Loepp,Victoria T(DOA)" <victoria.loepp@alaska.gov> Subject: RE: Endicott 3-09(PTD#1950190)No Flow Testing A pulling tool (minus the dogs)and appropriate prong can be used. I have done it on a few different style assemblies in the past. I can run by the wireline shop and see what they have if you would like. Lou Grimaldi Petroleum Inspector Alaska Oil and Gas Conservation Commission (907)776-5402(Home) (907)252-3409(Cell) Original message From: "Regg, James B (DOA)" Date:03/25/2015 19:00 (GMT-09:00) To: "Grimaldi, Louis R(DOA)" , DOA AOGCC Prudhoe Bay Cc: "Loepp,Victoria T(DOA)" Subject: RE: Endicott 3-09 (PTD#1950190)No Flow Testing Whatever it takes to confirm(no doubt)the SSSV is open. Jim Regg Supervisor, Inspections AOGCC 907-793-1236 Sent from Samsung Mobile Original message From: "Grimaldi, Louis R(DOA)" <lou.grimaldi@alaska.gov> Date: 03/25/2015 5:48 PM (GMT-09:00) To: "Regg,James B (DOA)" <iim.regg@alaska.gov>,DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bayalaska.gov> Cc: "Loepp,Victoria T(DOA)" <victoria.loepp a alaska.gov> Subject: RE: Endicott 3-09 (PTD#1950190)No Flow Testing I'm sorry but neither of their alternative methods seems positive to me. Maybe they could drift the valve with wireline. What type of valve and lock are we dealing with? Louis R. Grimaldi Petroleum Inspector Alaska Oil and Gas Conservation Commission 907-776-5402 (Home) 907-252-3409 (Cell) Lou.GrimaldiCa�Alaska.gov 2 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 Lou Grimaldi at 907-252-3409 or Lou.Grimaldi@Alaska.gov. From: Regg,James B(DOA) Sent: Wednesday, March 25, 2015 9:28 AM To: DOA AOGCC Prudhoe Bay Subject: FW: Endicott 3-09 (PTD #1950190) No Flow Testing Heads up. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.reggPalaska.gov. From: Loepp, Victoria T(DOA) Sent: Wednesday, March 25, 2015 9:20 AM To:Taylor Wellman Subject: RE: Endicott 3-09 (PTD #1950190) No Flow Testing Taylor, The performance and validity of this no flow test will be up to the State Inspector. On the web notification form the special circumstances and request will need to be outlined in the other remarks section. Proof that the SSSV is open throughout the test will need to be demonstrated to the Inspector's satisfaction. Please be aware that the Inspector's schedule is particularly busy at this time and scheduling this test with the special circumstances may be difficult. Hope this addresses your request. Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work. (907)793-1247 Victoria LoeprKaalaska qov 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 3 recipient of this e-mail,please delete it,w ir gout first saving or forwarding it,and,so that the AL ,CC is aware of the mistake in sending it to you,contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov From: Taylor Wellman [mailto:twellman@hilcorp.com] Sent: Friday, March 20, 2015 3:39 PM To: Loepp, Victoria T(DOA) Subject: Endicott 3-09 (PTD #1950190) No Flow Testing Victoria, Endicott 3-09(PTD#1950190) is a gas lifted production well. We would like to pursue conducting a No Flow test on this well. In typical circumstances we would not have the SSSV installed during the time of the No Flow test. For this well the wireline retrievable SSSV in the well has had a history of trouble in getting a valve to seal properly. The last SSSV used has a fully functioning valve with the aid of a swell o-ring. I would like to see if we would be able to leave the SSSV installed in the well during the No Flow test. Alternative Monitoring Methods Suggested - Upon arrival to site the inspector could watch the operator pressure up on the SSSV hydraulic line to watch the SSSV open. Conduct the normal No Flow test. - Conduct normal No Flow test. Close the SSSV and then pressure up on the SSSV hydraulic line to watch the SSSV open. Wellwork Objective: The plans for the well are to change the current GLV design in the well. To do the GLV work,the SSSV will need to be removed but I don't want to pull the SSSV without knowing that the well will not require an SSSV in the future(passing No Flow test). If you would like to discuss this further please give me a call. Thank you, Taylor Taylor Wellman Hilcorp Energy Company-Operations Engineer Office: (907)777-8449 Endicott: (907)777-8449 Cell: (907)947-9533 Email:twellman@hilcorp.com 4 PTD / — L l Loepp. Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Wednesday, March 25, 2015 9:20 AM To: 'Taylor Wellman' Subject: RE: Endicott 3-09 (PTD#1950190) No Flow Testing w/SSSV open Taylor, The performance and validity of this no flow test will be up to the State Inspector. On the web notification form the special circumstances and request will need to be outlined in the other remarks section. Proof that the SSSV is open throughout the test will need to be demonstrated to the Inspector's satisfaction. Please be aware that the Inspector's schedule is particularly busy at this time and scheduling this test with the special circumstances may be difficult. Hope this addresses your request. Victoria Victoria Loepp SCAMS) Senior Petroleum Engineer M+': 4 5 :.' State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work (907)793-1247 Victoria Loeppalaska qov 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 Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Taylor Wellman [mailto:twellman(ahilcorq.com] Sent: Friday, March 20, 2015 3:39 PM To: Loepp, Victoria T(DOA) Subject: Endicott 3-09 (PTD #1950190) No Flow Testing Victoria, Endicott 3-09(PTD#1950190) is a gas lifted production well. We would like to pursue conducting a No Flow test on this well. In typical circumstances we would not have the SSSV installed during the time of the No Flow test. For this well the wireline retrievable SSSV in the well has had a history of trouble in getting a valve to seal properly. The last SSSV used has a fully functioning valve with the aid of a swell o-ring. I would like to see if we would be able to leave the SSSV installed in the well during the No Flow test. Alternative Monitoring Methods Suggested - Upon arrival to site the inspector could watch the operator pressure up on the SSSV hydraulic line to watch the SSSV open. Conduct the normal No Flow test. - Conduct normal No Flow test. Close the SSSV and then pressure up on the SSSV hydraulic line to watch the SSSV open. 1 Wellwork Objective: The plans for the well are to change the current GLV design in the well. To do the GLV work,the SSSV will need to be removed but I don't want to pull the SSSV without knowing that the well will not require an SSSV in the future (passing No Flow test). If you would like to discuss this further please give me a call. Thank you, Taylor Taylor Wellman Hilcorp Energy Company-Operations Engineer Office: (907)777-8449 Endicott: (907)777-8449 Cell: (907)947-9533 Email:twellman@hilcorp.com 2 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Beved~incent Nathan Lowell Date: q Is~ [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: /si • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator @bp.com] Sent: Wednesday, October 09,2013 10:11 PM To: AK, OPS END OIM;AK, OPS END Facility&FieldO&M TL;AK, OPS END Board Operator; AK, OPS END AES Drillsite Lead;AK, OPS END Operations Lead Tech;AK, RES END Production Optimization Engineer,AK, D&C Wireline Operations Team Lead;AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan;Wallace, Chris D(DOA); Cinelli, Steven; Regg, James B(DOA) Cc: AK, D&C DHD Well Integrity Engineer, AK, D&C Projects Well Integrity Engineer, Climer, Laurie A Subject: OPERABLE: Producer END3-09/L-28A(PTD#1950190) Passing OART All, Producer END3-09/L-28A(PTD#1950190) had a passing warm OART completed on 10/07/2013 with a build-up rate of 1.5 psi/day,falling under the manageable by bleeds criteria.At this time,the well is reclassified as Operable,and may remain online as needed. Please call with any questions. Thank you, Laurie Climer r I �� (Alternate:Jack Disbrow) BP Alaska -Well Integrity Coordinator GVVGoa Wit% Organizan SCANNED D�� WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator @BP.com From: AK, D&C - I Integrity Coordinator Sent:Tuesday, Octo•- 11, 2013 7:22 PM To: AK,OPS END OIM; AK, ► END Faality&FieldO&M TL; AK, OPS END Board Operator; AK, OPS END AES Drilisite Lead; AK, OPS END Operations • Tech; AK, RES END Production Optimization Engineer; AK, D&C Wireline Operations Team Lead;AK, D&C Well Services 0• - 1 ons Team Lead; Cismoski, Doug A; Daniel, Ryan; 'chris.wallace @alaska.gov'; Cinelli, Steven Cc: AK, D&C DHD Well Integrity Engineer; Wills, .ne M; AK, D&C Well Integrity Coordinator; lim.regg @alaska.gov' Subject: UNDER EVALUATION: Producer END3-09/L- (PTD #1950190) MITIA Passed All, Producer END3-09/L-28A(PTD#1950190) passed a MITIA on 10/01/2013 • swing gas lift valve work. The well is reclassified as Under Evaluation to perform an outer annulus repressurization t while on gas lift, and is placed on a 28 day clock to facilitate evaluation. Plan forward: 1. Operations/DHD: Place well on production 2. DHD: Perform outer annulus repressurization test 1 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator @bp.com] Sent: Tuesday, October 01, 2013 7:22 PM To: AK, OPS END OIM; AK, OPS END Facility& FieldO&M TL; AK, OPS END Board Operator; AK, OPS END AES Drillsite Lead; AK, OPS END Operations Lead Tech; AK, RES END Production Optimization Engineer; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; Wallace, Chris D (DOA); Cinelli, Steven Cc: AK, D&C DHD Well Integrity Engineer; Wills, Shane M; AK, D&C Well Integrity Coordinator; Regg, James B (DOA) Subject: UNDER EVALUATION: Producer END3-09/L-28A(PTD #1950190) MITIA Passed Attachments: END3-09_L-28A(PTD 19510190)TIO Plot.docx All, Producer END3-09/L-28A(PTD#1950190) passed a MITIA on 10/01/2013 following gas lift valve work. The well is reclassified as Under Evaluation to perform an outer annulus repressurization test while on gas lift, and is placed on a 28 day clock to facilitate evaluation. Plan forward: 1. Operations/DHD: Place well on production 2. DHD: Perform outer annulus repressurization test Please use caution while bringing on the well due to fluid packed annuli. A copy of the TIO plot is included for reference. Please call with any questions. DEL SCAM) D . 1U13 Thank you, Jack Disbrow BP Alaska Well Integrity Coordinator C Global Wells Organization Office: 907.659.5102 WIC Email:AKDCWelllntegrityCoordinator(a)bp.com From: AK, D&C Well Integrity Coordinator Sent: Thursday, July 11, 2013 10:45 PM To: AK, OPS END OIM; AK, OPS END Facility &FieldO&M TL; AK, OPS END Board Operator; AK, OPS END AES Drillsite Lead; AK, OPS END Operations Lead Tech; AK, RES END Production Optimization Engineer; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; Cinelli, Steven; 'Regg, James B (DOA)'; 'Schwartz, Guy(DOA) <ouv.schwartz@alaska.gov>' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; Climer, Laurie A Subject: NOT OPERABLE: Producer END3-09/L-28A(PTD# 1950190) OA over MOASP All, Producer END3-09/L-28A(PTD#1950190) is currently Under Evaluation due to the OA breaking MOASP. At this time, further diagnostics cannot be completed due to operational needs.The well is reclassified as Not Operable,and will remain shut in until further work can be performed. 1 • S Thank you, Laurie Climer BP Alaska - Well Integrity Coordinator cito ai y el'#s ‘a r gani2atton WIC Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator @BP.com From: AK, D&C Well Integrity Coordinator Sent: Thursday, June 20, 2013 2:17 PM To: AK, OPS END OIM; AK, OPS END Facility & FieldO&M TL; AK, OPS END Board Operator; AK, OPS END AES Drillsite Lead; AK, OPS END Operations Lead Tech; AK, RES END Production Optimization Engineer; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; Cinelli, Steven; 'Regg, James B (DOA)'; 'Schwartz, Guy (DOA) <guy.schwartz@alaska.gov>' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; Climer, Laurie A Subject: UNDER EVALUATION: Producer END3-09/L-28A (PTD# 1950190) OA over MOASP All, Producer END3-09/L-28A (PTD# 1950190) OA broke MOASP on 06/17/13 with TBG/IA/OA = 380/1680/1720 psi. A failing PPPOT-IC on 6/19/13 indicated the secondary seals are suspect.The well previously experienced a thermal event on 06/09/13, passing a subsequent OART. At this time the well has been reclassified as Under Evaluation,and may remain online as needed for further evaluation. Plan Forward: 1. Wellhead: Re-energize Y-seals 2. DHD: Perform OART, cycle the well 3. WIE: Further Diagnostics as needed A copy of the wellbore schematic has been included for reference. Please call with any questions. Thanks, Laurie Climer (Alternate:Jack Disbrow) BP Alaska - Well Integrity Coordinator MA/ Gto al Wells rr77 V V Organizatglo WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator @BP.com 2 S • END3-09/L-28A(PTD#1950190)TIO Plot Well:3� 4,000 7 - 3000 t 2.000 --.0—OA OOA —0—0000 1.000 111111k......."".11101011.110PPOOPPIMM004.10010014. 07,9511 07n3113 07.2013 0112E13 07Y0113 0810 3 03'7^3 0074,3 1875113 000.,3 0414.13 037,713 042313 Fndt4,* 3 (A Irlsot tCi .Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator @bp.com] Sent: Thursday, June 20, 2013 2:17 PM �C'f 61 tel t 3 To: AK, OPS END OIM; AK, OPS END Facility& FieldO&M TL; AK, OPS END Board Operator; AK, OPS END AES Drillsite Lead; AK, OPS END Operations Lead Tech; AK, RES END Production Optimization Engineer; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; Cinelli, Steven; Regg, James B (DOA); Schwartz, Guy L(DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; Climer, Laurie A Subject: UNDER EVALUATION: Producer END3-091L-28A(PTD# 1950190) OA over MOASP Attachments: END3-09 Wellbore Schematic.pdf; Producer END3-09 TIO 06-19-13.docx All, ✓ Producer END3-09/L-28A (PTD# 1950190) OA broke MOASP on 06/17/13 with TBG/IA/OA = 380/1680/1720 psi. A failing PPPOT-IC on 6/19/13 indicated the secondary seals are suspect.The well previously experienced a thermal event on 06/09/13, passing a subsequent OART. At this time the well has been reclassified as Under Evaluation, and may = remain online as needed for further evaluation. Plan Forward: 1. Wellhead: Re-energize Y-seals - OD FEB 2 0 2.O 2. DHD: Perform OART, cycle the well - SCO 3. WIE: Further Diagnostics as needed A copy of the wellbore schematic has been included for reference. O,4 cP Please call with any questions. " 172�,� 5v-zor5 Thanks, %iutr_iff'= 34,3`4, Laurie Climer (Alternate:Jack Disbrow) BP Alaska - Well Integrity Coordinator Go4a1 Weis rganiz i otl WIC Office: 907.659.5102 WIC Email: AKDCWellIntegritvCoordinator @BP.com 1 ' M _ — M I• � M , M M Co d .1� M_ _t7S O u1 M t N i M o O. ul 01 o m co p \ 0 N d l0 01 TREE= CM/ S, (NOTES:H2S READINGS AVERAGE 230-260 WELLHEAD= MCEVOY JMD DR T END3-09 � ACTUATOR= BAKER C ° PP1w ON AIL&GAS INJECTORS. WELL REQUIRES A SSSV. 4-1/2"CHROME TBG&NIPPLES BF..ELEV= 56 BF ELEV= KOP= 1504' H4-1/2"HXO SVLN, ID=3.813" 1 Max,Angle= 64'@ 8200' Datum MD= �� 14324' Datum TVD= 10000 S5 /44 I, GAS LIFT MANDRELS ST MD TVD DEV VLV LATCH PORT DATE 13-3/8"CSG,684,L-80 BTRS.ID=12.415" —I 2512' I f 111 5 3574 3574 1 DOME RA 16 03/07/00 4 4492 4479 18 SO RM 26 01/28/06 M1 = 0 ztprs, 3 5734 5509 47 DMY RA 0 04/27/95 2 7441 6472 59 DMY RA 0 04/27/95 1 8145 6808 63 DMY RA 0 04/27/95 8179' I—I9-5/8"X 7"TIEBACK TM/PKR, ID=6.18" I Minimum ID = 3.725" @ 12393' X 4-1/2" HES XN NIPPLE 1 ,---- I 12307' 1--14-1/2"HES X NIP,ID=3.813" I z >- 12319' H7"X 4-1/2"BKR SAB-3 PKR, ID=3.870" 1 I V 12382' I—I4-1/2"HES X NIP. ID=3.813" 1 ----- J 12393' H4-1/2"HES XN NIP,ID=3.725" 1 4-1/2"TBG, 12.64, 13-CR NSCT, —I 12406' j—.._J \— _ 12406' H4-1/2"WLEG, ID=3.958" I .0152 bpf, ID=3.958" TOP OF 5"LNR —1 12477' I j a 0-5/8"CSiC.47//.?, ..... . --I '! 17"LNR,264, L-80 LTC-M, .0383 bpf, ID=6.276" I—I 12638' IL PERFORATION SUMMARY OP REF LOG: SBT on 04/13/95 12643' - 12693'I-19-5/8"SIDETRACK WINDOW 1 ANGLE AT TOP PERF: 59°@ 13971' g Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE r 2-7/8 4 13970- 13990 S '2-7/8 4 13971 - 13994 0 ®2-7/8 4 14002- 14032 S ®2-7/8 6 14004- 14050 0 ir 2-7/8 6 14034- 14054 S r 2-7/8 6 14062- 14082 S ®2-7/8 4 14070- 14100 S r 3-3/8 4 14138- 14150 S r 3-3/8 4 14166-14178 S v 3-3/8 4 14192- 14214 S 2-1(2 4 14210- 14214 S I 14256' H BKR 3-3/8"IBP(06/18/07) I 14220- 14258 S 14266- 14292 0 14308- 14312 S 14360- 14364 S 14488- 14492 S 14526' I---I POST SQZ TD??? PBTD —1 14554' ►y.w'1 5"LNR, 18#,L-80 LT&C, H 14650' •'',''''♦'/'' .0178 bpf,ID=4.276" DATE REV BY COMMENTS DATE REV BY COMMENTS ENDICOTT UNIT 05/08/95 JTP SIDETRACK COMPLETION 02/23/07 JCM/TLH PLUG PULLED 03/27/06 WELL: 3-09/L-28A 10/18/95 JTP ADPERFS 06/16/07 KSB/PJC 7"PKR CORRECTION PERMIT No: 1950190 05/12/98 DB POST SQZ PERFS 11/30/10 ?/JMD REFORMATTING API No: 50-029-21780-01-00 08/15/98 DB ADPERFS 02/17/11 MB/JMD ADDED SSSV SAFETY NOTE SEC 8,T11N,R17E,2530'FNL&838'FEL 01/28/06 RMH/PJC GLV C/O 08/15/11 DW/JMD ADDED H2S SAFETY NOTE 01/29/06 TEL/PJC PXN PLUG @ 12393' BP Exploration (Alaska) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 22, 2012 Mr. Jim Regg 7th �_ Alaska Oil and Gas Conservation Commission >Iq 333 West Avenue p t © Anchorage, Alaska 99501 Y ,/ Subject: Corrosion Inhibitor Treatments of Endicott Row 3 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from Endicott Row 3 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Endicott Row 3 Date: 10/03/10 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal END3 -01 / N -29 1861900 50029216780000 7.0 4.4 0.3 9/6/2010 1.70 10/3/2010 END3 -03 / J-33 1921210 50029223060000 8.0 6.1 0.3 9/6/2010 2.55 10/3/2010 END3 -05 / 0 -29 1861300 50029216240000 3.0 2.0 0.5 9/6/2010 3.40 10/3/2010 END3 -07A / L -29 1981470 50029219110100 2.0 0.5 0.3 9/6/2010 1.70 10/3/2010 7END3 -09 / L -28A 1950190 50029217800100 0.1 NA 0.1 NA 1.00 10/3/2010 END3 -15 / K -33 1870940 50029217510000 0.1 NA 0.1 NA 1.00 10/3/2010 END3 -17F / K -30 2032160 50029219460600 1.5 0.5 0.5 9/6/2010 2.55 10/3/2010 END3 -19 / R -28 1940490 50029224630000 10.0 17.0 0.3 9/6/2010 1.70 10/3/2010 END3 -21 / L -34 1870330 50029217140000 23.0 14.5 1.1 9/6/2010 13.60 10/3/2010 END3 -23 / N-32 1861550 50029216450000 1.5 1.0 0.5 9/6/2010 3.40 10/3/2010 END3 -27 / M-33 1860830 50029215860000 1.0 0.1 0.6 _ 9/6/2010 2.55 10/2/2010 END3 -29 / J -32 1901560 50029221060000 2.0 1.0 _ 0.6 9/6/2010 3.40 10/2/2010 END3 -31 / K -32 1972270 50029228380000 2.0 3.0 0.5 9/6/2010 3.40 10/2/2010 END3 -33A / J -35 2032150 50029216680100 0.5 NA 0.5 NA 3.40 10/2/2010 END3 -35 / L -36 1870200 50029217010000 10.0 7.0 0.4 9/6/2010 3.40 10/2/2010 END3 -37 / L -35 1950510 50029225540000 8.0 7.3 0.3 9/6/2010 1.70 1012/2010 END3 -39A /1-37 1970910 50029217640100 1.0 0.8 0.7 9/6/2010 3.40 10/2/2010 END3 -49A / M-40 1970570 50029217350200 0.4 NA 0.4 NA 1.70 10/2/2010 STATE OF ALASKA ALA?''--'~, OIL AND GAS CONSERVATION COMMIS REPORT L,-,= SUNDRY WELL OPERATIONS 1. Opemtior~s performed: Operation shutdown__ Stimulate__ Plugging__ Perforate~ Pull tubing__ Alter casing __ Repair well Other__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora_cle, Alaska 99519-6612 4. Location of well at surface 2530' NSL, 838' WEL, Sec. 8, TIIN, R17E At top of productive interval 3472' NSL, 345' WEL, Sec. 5, TIIN, R17E At effective depth 3995' NSL, 86' EWL, Sec. 4, TIIN, R17E At total depth 4056' NSL, 191' EWL, Sec. 4, T11N, R17E 5. Type of Well: Development .. Exploratory __ Stratigraphic __ Service __ 6. Datum elevation (DF or KB) KBE = 55.4 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-09/L-28A SDI 9. Permit number/approval number 95-19~Not required 10. APl number 50- 029o21780-01 11. Field/Pool Endicott Field/Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 14700 feet 10287' BKB feet 14541 feet 10185' BKB feet Plugs (measured) Junk (measured) 3-3/8" Inflatable Bridge Plug (IBP) 14258'- 14266'. Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth BKB BKB 122' 2473' 10481' 4449' 2173' 30" Driven 161' 161' 13 3/8 3254 C. F. Permafrost 2512' 2488' 9 5/8" 1150 C. F. Class "G" 10520' 7919' 7" 112 C. F. Class "G" 8189'- 12638' 6803'- 9129' 5" 1095 C. F. Class "G" 12477'- 14650' 9044'- 10225' measured 12515'- 12517'; 13970'- 13990', 14002'- 14032', 14034-14054', 14070'- 14100', 14138'-14150', 14166'-14178', 14192'- 14214', 14220'-14258', 14308' - 14312', 14360' - 14364', 14488' - 14492' (Ail Squeezed) 13974'- 13994'; 14004'- 14050', 14062'- 14082', 14266'- 14292', 14481'- 14490' (Ail Open) true vertical (Subsea) 9032'- 9033'; 9809'- 9820', 9826'- 9842', 9843'- 9853; 9862'- 9878', 9898'- 9904', 9913'- 9919', 9927'- 9939; 9942'- 9963', 9991'- 9998; 10020' - 10023', 10096 '- 10098' (Afl Squeezed) 9811'- 9822;' 9824'- 9851', 9857'- 9868', 9967'- 9982; 10092'- 10097' (All Open) Tubing (size, grade, and measured depth) 4 1/2" 12.6#/ft, 13 CR tubing set at 12405' Packers and SSSV (type and measured depth) 7"packer set at 12319', 4 1/2 SSSV set at 1504' 13. Stimulation or cement squeeze summary Set XXN plug in XN nipple @ 12356' (2/29/00); Pull plug from XN Nipple (3/8/00) Intervals treated (measured) Treatment description including volumes used and final pressure see Attached. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 1459 1443 9775 0 414 1066 1422 11069 0 442 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations × 16. Status of well classification as: Oil x Gas.__ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SeN, ice Date 03/27/00 SUBMIT IN DUPLICATE~ Form 10-404 Rev 06/f'1-5/88 BPX Endicott Production Engineering Department OPERATIONS REPORT DATE: 3-8-00 WELL N°: 03-09/L-28A TYPE OF OPERATION: PULL PLUG FROM XN NIPPLE BP EXPLORATION REP: PERUZZI T. SERVICE COMPANY: HES / JORDAN DATE/TIME OPERATIONS SUMMARY SIP: 300 lAP:0 OAP:0 12:00 TGSM/(NEW CREW, WIND CODITIONS, CHILL FACTOR, PROCEDURES) 12:30 I DIG OUT WALKWAYS TO WELL, AND COMMENCE RIGGING UP 13:45 RIH W/2 1/8 ROLLER STEM, 2.9 WHEELS, 4 1/~ GS. EXTREMELY SLOW GOING. 14:30 REACH XN NIPPLE @ 12356 WLM, AND LATCH ONTO XXN PLUG 15:45 I COMMENCE OUT OF HOLE W/PLUG. 16:30 I REACH SSSV NIPPLE AND PROCEED TO BEAT PLUG THROUGH 17:00t BLEED OFF LUBRICATOR INTO BLEED TANK 17:20 I VISUALLY CONFIRM PLUG ON SURFACE 17:30I PRE- RIG DOWN TGSM 17:40 ! RIGDOWN SUMMARY: PULLED XXN PLUG OUT OF XN NIPPLE. SSSV: OUT BPX Endicott Production Engineering Department OPERATIONS REPORT DATE: 03/04/00 WELL N°: 3-09 / L-28a TYPE OF OPERATION: PREP FOR T-SEAL REPAIR BP EXPLORATION REP: DAN ROBERTSON SERVICE COMPANY: HES / NYQUIST DATE/TIME OPERATIONS SUMMARY SIP:100# lAP:0# CAP:0# 0845 SAFETY MEETING RIG-UP,OPEN SSV W/ENERPAC 1040 RIH W/4 ~,,~ .... XX" PLUG,TOOLS SAT DOWN @ 7,550' WLM,ATTEMPTED TO WORK DOWN HOLE,UNABLE TO WORK PAST 7,677' WLM,LOST PLUG @ 7,380' WLM 1230 RIH W/4 !&" GS TO 7,392' WLM,OOH W/PLUG,TBG NOW 50# 1445 RIH W/4 ~" DUMMY BALL VALVE PLUG TO SVLN @ 1,465',SET,TEST, PUMPED 1/~ BBL OF DIESEL,TO 1,000#,BALANCE & CONTROL LINES CAME UP TO 1,000#,TUBING,CONTROL & BALANCE LINES ALL BLEEDING DOWN. BLEED DOWN TUBING, BALANCE, CONTROL LINES, IA & FLOW LINE TO 0# 1658 RIG DOWN,SPOT UNIT ON 4-08 SUMMARY: ATTEMPT TO SET 4 1,,~ .... XX" PLUG SET 4 1/~,, DUMMY BALL VALVE / PLUG IN SVLN BLEED TBG,IA TO 0# NOTE: TO EQUALIZE DUMMY BALLVALVE/PLUG USE 2' X 1 7/8" STEM W/X EQUALIZING PRONG SSSV: OUT STATE OF ALASKA ALA-"' -" OIL AND GAS CONSERVATION COMMI,c N REPORT L,r: SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown__ Stimulate__ Plugging__ Pull tubing__ Alter casing __ Repair well __ 2. Name of Operator BP Exploration (Alaska) Inc. 3. AddresS P. O. Box 196612, Anchora.c~e, Alaska 99519-6612 5. Type of Well: Development .. Exploratory ~ Stratigraphic ~ Service __ Perforate X Other__ ,~;~m<',~ (.)il & Gas C0r~s, 6. Datum elevation (D~6~f~l~e KBE = 55.4 feet 7. ~operty name Duck Island Unit/Endicott 4. Location of well at surface 2530' NSL., 838' WEL, Sec. 8, TIIN, R17E At top of productive interval 3472' NSL, 345' WEL, Sec. 5, TIIN, R17E At effective depth 3995' NSL, 86' EWL, Sec. 4, TIIN, R17E At total depth 4056'NSL, 191'EWL, Sec. 4, T11N, R17E 12. Present well condition summary Total depth: measured true vertical 14700 feet 10287' BKB feet Plugs (measured) 8. Well number 3-09/L-28A SDI 9. Permit number/approval number 95-19/Not recluired 10. APl number 50- 029-21780-01 11. Field/Pool Endicott Field/Endicott Pool 3-3/8" Inflatable Bridge Plug (IBP) 14258'- 14266'. Effective depth: measured true vertical 14541 feet 10185' BKB feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth BKB BKB 122' 2473' 10481' 4449' 2173' 30" Driven 161' 161' 13 3/8 3254 C. F. Permafrost 2512' 2488' 9 5/8" 1150 C. F. Class "G" 10520' 7919' 7" 112 C. F. Class "G" 8189' - 12638' 6803' - 9129' 5" 1095 C. F. Class "G" 12477'- 14650' 9044'- 10225' measured 12515'- 12517'; 13970'- 13990', 14002'- 14032; 14034-14054', 14070'- 14100', 14138'-14150', 14166'-14178', 14192'- 14214', 14220'-14258', 14308' - 14312; 14360'- 14364', 14488' - 14492' (All Squeezed) 13974'- 13994'; 14004'- 14050', 14062'- 14082', 14266'- 14292', 14481'- 14490' (All Open) true vertical (Subsea) 9032'- 9033'; 9809'- 9820', 9826'- 9842; 9843'- 9853', 9862'- 9878', 9898'- 9904', 9913'- 9919', 9927'- 9939', 9942'- 9963', 9991'- 9998', 10020' - 10023', 10096 '- 10098' (All Squeezed) 9811'- 9822;' 9824'- 9851', 9857'- 9868', 9967'° 9982', 10092' - 10097' (All Open) Tubing (size, grade, and measured depth) 4 1/2" 12.6#/ft, 13 CR tubing set at 12405' Packers and SSSV (type and measured depth) 7" packer set at 12319', 4 1/2 SSS V set at 1504' 13. Stimulation or cement squeeze summary Add Perforations (8/15/98) Intervals treated (measured) 13974,-13994, Treatment description including volumes used and final pressure see Attached. . . = 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 2146 3483 9775 0 2283 4371 11069 0 Tubing Pressure 448 461 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas__ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. · Form 10-404 Rev 06/1~ Date 09/03/98 SUBMIT IN DUPLICATE BPX Endicott Production Engineering Department DATE: 8/15~98 WELL N°: 3-09/L-28A BP EXPLORATION REP: Additional Perforations D. Barba Cost Code: N15309-120 Detail Code: E Line/Add Peff/E Line SERVICE COMPANY: SWS (V. Lomax) DATE/TIME OPERATIONS SUMMARY 0800 0850 0900 0910 1005 1015 1016 1020 1035 1048 1100 1230 1300 MIRU SWS. WHP = 450 psig, WHT = 190 deg F, 120 psig, Choke = 176 Beans. Shut-in gas lift and well (wing). lAP = 1490 psig, OAP = Hold Safety Meeting Pressure test lubricator to wellhead pressure. RIH with Gun #1 (20') 2 718" @ 4 SPF, 60/120 DEG PHASING AND RANDOM ORIENTATION. CCL TO TOP SHOT 6.2'. Note ran one set of rollers on bottom. Out of the tubing tail. FLOW WELL AT 20 BEANS (without gas lift). MAKE TIE-IN PASS. MAKE -15' CORRECTION. Having trouble getting on depth, due to the frictional drag from the 13 Cr tubing. Close still trying. PARK CCL 13968' AND SHOOT (TS 13974' BS 13994'). NO INDICATION. SHUT-IN WELL. POOH OOH. Confirm all shots fired. RDMO SWS. PERFORATION SUMMARY: GUN INTERVAL SBT DEPTH 1 13974-13994 FEET SUBZONE 20 2B All intervals were shot using 2 7/8" guns With deep penetrating charges at 4 spf, 60/120 degree phasi/ig and random orientation. STATE OF ALASKA ALASK-~-'-'3- IL AND GAS CONSERVATION COMMISSIOn; REPORT O, SUNDRY WELL OPE...ATIONS 1. Operations performed: Operation shutdown. Stimulate X Plugging Pull tubing__ Alter casing __ Repair well __ Perforate X Other_x_ 2. Name of Operator BP Exploration (Alaska) Inc. ~. Address P. O. Box 196612, Anchora.cle, Alaska 99519-6612 4. Location of well at surface 2530' NSL, 838' WEL, Sec. 8, TIIN, R17E At top of productive interval 3472' NSL, 345' WEL, Sec. 5, TIIN, R17E At effective depth 3995' NSL, 86' EWL, Sec. 4, TIIN, R17E At total depth 5. Type of Well: Development .. Exploratory __ Stratigraphic __ Service __ 6. Datum elevation (DF or KB) KBE = 55.4 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-09/L-28A SDI 9. Permit number/approval number 95-19~Not required 10. APl number 50- 029-21780-01 11. Field/Pool 4056'NSL, 191'EWL, Sec. 4, T11N, R17E 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 14700 feet 10287' BKB feet 14541 feet 10185' BKB feet ....... nr,~.~;. CO~¢,~.,,~o-'t Endicott Field/Endicott Pool ~,-,~.w.q ',. ~.~, ~:'~ ~-~-'~ ...... Plugs (measured) 3-3/8" Inflatable Bridge Plug flBP) 14258'-14266t Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth BKB BKB 122' 2473' 10481' 4449' 2173' 30" Driven 161' 161' 13 3/8 3254 C. F. Permafrost 2512' 2488' 9 5/8" 1150 C. F. Class "G" 10520' 7919' 7" 112 C. F. Class 'G" 8189' - 12638' 6803' - 9129' 5" 1095 C. F. Class "G' 12477'- 14650' 9044'- 10225' measured 12515'- 12517'; 13970'- 13990', 14002'- 14032', 14034-14054; 14070'- 14100', 14138'-14150', 14166'-14178', 14192'- 14214', 14220'-14258', 14308' - 14312; 14360' - 14364', 14488' - 14492' (Al~ Squeezed) 14004'- 14050', 14062'- 14082', 14266'- 14292', 14481'- 14490' (Al~ Open) true vertical (Subset) 9032'- 9033;' 9809'- 9820', 9826'- 9842', 9843'- 9853', 9862'- 9878', 9898'- 9904', 9913'- 9919', 9927'- 9939', 9942'~ 9963', 9991'- 9998; 10020' - 10023', 10096 '- 10098' (Al~ Squeezed) 9824'- 9851', 9857'- 9868', 9967'- 9982', 10092'- 10097' (All Open) Tubing (size, grade, and measured depth) 4 1/2" 12.6#/ft, 13 CR tubing set at 12405' Packers and SSSV (type and measured depth) 7"packer set at 12319', 4 1/2 SSSV set at 1504' ORtGllxIAL 13. Stimulation or cement squeeze summary Add Perforations (4/23/98) WSO/Cement Squeeze (5/2/98) MIT (5/1/98) Post Squeeze Perforations (5/12/98) Intervals treated (measured) 125~5,- 12517,; 13970,- 13990,, 14002,. 14032,, 14034-14054,, 14070,- 14100; 14138;14150,, 14166;14178,, 14192,- 14214,, 14220,-14258; 14308, - 14312,, 14360,- 14364; 14488,- 14492,; 14004,- 14050,, 14062,- 14082,, 14266,- 14292,, 14481,- 14490, Treatment description including volumes used and final pressure See Attached. 14. Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 2927 3812 124 77 0 4 72 3O45 6960 10797 0 523 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas__ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ' ' -~ -/~ - _ .... Form 10-404 Rev 06/1~8 Date 6/3/98 SUBMIT IN DUPLICA~ BPX Endicott Production Engineering Department Post-SQZ Perforations DATE' 5/12/98 Cost Code: Nt0309-120 WELL N°: 3-09/L-28A Detail Code: CMT SQZ/Post SQZ Perf/E Line BP EXPLORATION REP: D. Varble/D. Barba SERVICE COMPANY: SWS (J. SpenceflS. Deckert) DATE/TIME 0800 5/13 0845 0955 1005 1035 1150 1200 1205 1230 1250 1405 1445 OPERATIONS SUMMARY 1610 1628 1730 1735 1845 1900 MIRUSWS. WHP= 350psig, WHT= 135degF, lAP= 1000psig, OAP=0 psig. Note well in test, flowing at ~1800 bpd. Kicked off to under balance on 5/11/98 at approximately 1830 hours. Well head sample looks to be all water. Shut-in well. Hold Safety Meeting Call for Radio Silience and post signs. Pressure test lubricator to wellhead pressure. RIH with Gun #1 (20') 2 7/8" @ 6 SPF, 60 DEG PHASING AND RANDOM ORIENTATION. CCL TO TOP SHOT 5.8'. Note ran one set of rollers on bottom. Out of the tubing tail. FLOW WELL AT 25 BEANS (without gas lift). MAKE TIE-IN PASS. MAKE +1.5' CORRECTION.Tie into SBT Dated 4/13/95. PARK CCL 14056.2' AND SHOOT (TS 14062' BS 14082'). Good cap break, lost 150 lbs, and no change in WHP. SHUT-IN WELL. POOH OOH. Confirm all shots fired. Pressure test lubricator to wellhead pressure. RIH with Gun #2 (26') 2 718" @ 6 SPF, 60 DEG PHASING AND RANDOM ORIENTATION. CCL TO TOP SHOT 6.35. Note ran one set of rollers on bottom. Tag TD and log up for tie4n Gun stuck at ~14040'. Discuss options. Pulled out of head @ 3085#. POOH. Near surface (-,,50') pulling weight due to high strand. Cable still across swab valve. Increase pull 1500#, 2000# and 2500#. Free! Close swab valve. 1915 2000 O945 1050 1100 1105 1130 1250 1305 1310 Release radio silience. RDMO SWS. MIRU HES. MIRU SWS Shut-in well. Hold Safety Meeting Call for Radio Silience and post s~gns. Pressure test lubricator to wellhead pressure. RIH with Gun #2 (20') 2 7/8" @ 6 SPF, 60 DEG PHASING AND RANDOM ORIENTATION. CCL TO TOP SHOT 5.8'. Note ran one set of rollers on bottom. Out of the tubing tail. FLOW WELL AT 25 BEANS (without gas lift). MAKE TIE-IN PASS. MAKE -21' CORRECTION.Tie into SBT Dated 4/13/95. DATE: 5-12-98 WELL N°: 3-09/L-28A TYPE OF OPERATION: OPERATIONS REPORT CONTIN tJED Post SQZ Perforations 1330 1335 1340 1510 1545 1650 1700 1715 1730 1740 1835 1848 1915 2000 PARK CCL at 14024.2' AND SHOOT (TS 14030' BS 14050'). Good cap break, lost 75 lbs, and no change in WHP. Stop and flag line at 13900'. SHUT-IN WELL. POOH OOH. Confirm all shots fired. Pressure test lubricator to wellhead pressure. RIH with Gun #3 (26') 2 7/8" @ 6 SPF, 60 DEG PHASING AND RANDOM ORIENTATION. CCL TO TOP SHOT 3.5'. Note ran one set of rollers on bottom. Out of the tubing tail. Stop at flag reset depth(make -20' correction). MAKE TIE-IN PASS. MAKE -5' CORRECTION.Tie into SBT Dated 4/13/95. FLOW WELL AT 25 BEANS (without gas lift). PARK CCL at 13997.5' AND SHOOT (TS 14004' BS 14030'). Good cap break, lost 100 lbs, and no change in WHP. SHUT-IN WELL. POOH. OOH. Confirm all shots fired. Off well head. Confirm all shots fired. Release radio silience. Put well on production. RDMO SWS. PERFORATION SUMMARY: GUN INTERVAL SBT DEPTH 1 '-~14062-14082 3 --~14004-140.30 FEET SUBZONE 20 2B 20 2B 26 2B All intervals were shot using 2 7/8" guns with deep penetrating charges at 6 spf, 60 degree phasing and random orientation. WSA WELL REPORTS To: Anchorage Engineering Group Date: 05-02-98 From: Clump / Quesenbury Re: Endicott Well 3 - 09 / L-28 a SUMMARY 5/2/98 Attempt to Fish IBP: Unable to recover Baker IBP ~ 14256' w/one attempt. Got latched up, but lost after first jar lick. Rigged up slick line on BOP's. 5/3/98 Made Impression block run, but came back w/no impression of fishing neck. Made two bailer runs and recovered formation sand. Bailer came back w/marks from IBP fishing neck. Made 2 runs to attempt to set overshot. Call Anchorage and decision was made to leave IBP and perform cmt WSO above IBP. WSO: Rig up w/3" combo nozzle. Start BH kill. Tag IBP ~ 14256'. Pull above perfs and pump ~ min rate until pumpers arrive. Pump 15.2 bbls 15/10 HCL/Xylene. Reciprocate down to IBP. Mix and pump 21 bbls Latex cmt (86 cc FL, 0.8" Filter Cake). Ramp to 3000 psig after moving cmt behind pipe several times. Difficult to say how much put behind pipe (blind -gas on back side), but would guess ~ least 5 bbls total. Contaminated cmt with biozan & layed TEA across perfs. Chased contaminated cmt out of the hole with Slick water. FP well to 1200'. Left 700 psig trap on squeeze. IBP left ~ 14256'. Squeeze was nearly JFT (probably wing valve leaking to flowline). ITime I Operations 0100 Move in Squeeze Unit & RU. 0430 RU DS Unit # 2. 0630 DS having operational safety meeting RU Baker toolstring to pull IBP. 0905 PT toolstring to 4000 psig. Good. 0931 PT lubricator w/meoh. Line up to recover meoh. Pre-set to 16.5' 1022 Recover 30 bbls meoh to squeeze tank. 1024 Open swab valve. IAP= 150 psig, 0AP= 0 psig, Whp= 1900 psig. Come on line pumping FSW. 3-09 WSO 5-3-98 1 Time II CTD I[ CTP II WHp II Rate I[ Vol. [ Comments 1052 - 1157 1140 5/1.5 63 Rib w/IBP fishing string. 1110 1049 864 864 1.5/0 90.4 Level wind is stripped out. Fix. 1305 10000 380 380' 2 282 PU 17.5 k. 1320 11450 233 360 2 310/0 Switchto meoh. 1328 11633 1600 324 2 5/0 Backside line is FP, switch to coil side only. 1350 12000 1500 287 0 11 PU 22 k. 1340 13000 3922 278 1.6 30 PU 23 k. 1345 13500 526 260 0 36 Coil FP. 1342 14009 489 287 0 24 k. 1404 14273 489 306 0 12.2 k down ~ 48 fpm. 1,406 14273 452 306 0 Missed. 1410 1800 333 1 Rih 50 fpm. Set down cut pump. 5000# down. 1413 14273 Have latch. Set down fast. Pull up 30k. Jars go off. 1415 14250 470 360 0 Set here for 15 mins. 1426 14243 489 360 0 Rih to 14267. 1442 14253 3800 452 1.5 0 Rih pumping down faster 1446 14270 471 450 1.5/0 10 7000# down. Pull up hole-no plug. 1500 14270 471 516 0 Set down 1510 14270 PU 14260' don't have it. 1520 14270 461 672 10 Try several more things. 1740 - -68 873 0/.57 0/2 Pump methanol to fill coil 1809 -. OOH. Tool looks fine. Rig up slick line. 1845 0 0 350 0 0 RIH w/LIB to 14,250' WLM. POH. ~ surface. No impression of IBP fishing neck. RIH w/2- 1/4" bailer. Bail top of IBP. POH. 2330 0 0 325 0 0 ~ surface, recovered 2/3 of a gal. of form. Sand. No visible indentions on bottom of bailer to indicate top of F.N.. 2345 0 0 325 0 0 RIH w/bailer. Bail ~14250' WLM. POH. Rec. ½ pint of sand. Bottom of bailer showed indents of TOF. MU overshot & 3-09 WSO 5-3-98 2 Time II CTD II CTP [I WHP II Rate II Vol. I[ Comments GS. ( 05-03-98 ) 0400 0 0 0 0 RIH w/overshot to attempt to bait top of FN. 0700 0 0 0 0 OOH w/overshot. 1015 Rigged up w/3" combo nozzle. 1115 - 4000 4000 min 3 PT to 4000 psig 1153 - 1500 950 1.5 30 Recovered Meoh to coil w/SW. 1218 - 635 400 5 109 1255 - 178 1560 5/1 320 Rihw/combo nozzle. 1346 500 214 1432 1/min 426 1540 14256 269 1148 1 550 Tag IBP and correct depth. 1551 13962 278 1000 1 604 1720 13962 200 80 0 720 Shut down for WHP check. 1730 13962 223 1390 1.1 728 23.k 1745 13962 251 1047 1 760 Cmtr's rigged up-taking on water. 1838 14252 372 3170 1.8 836/0 1916 14252 97 1150 0 70 Switch to meoh to FP pump. 1930 14252 112 465 0.5 71/0 Come on line w/cmt. Go for PT. Start shearing cmt. 1945 14252 157 3235 2.56 54 2045 14252 157 3755 3.86 145 Circulate out gas. 5 hrs 30 min. 2108 14252 146 2135 2.5 239/0 On Acid. We are going to do this blind. 2116 14252 157 3411 2.41 15.2 On FSW. 2t25 14252 172 3615 2.40 36.5 Lay in acid. 60 fpm. 2130 14256 179 3512 2.40 51.5 Tag IBP. Overdisplace onthe way out. 2135 13950 179 3832 2.3 65 At the top. 2144 13950 190 3900 2.1 82 Crack choke briefly. 2156 14104 183 2800 2.1 110 2205 14104 170 3800 2.1 125 6minmoreto 30min. 86ml. 0.8". 2222 13951 176 3800 2.1 160/ Switch to Fresh water. 2226 13951 181 3752 2.0 0 On cmt. 2238 14150 3652 190 1.8 21 Cmt away, switch to f. Water 27.6 k up 2244 14178 1035 200 1.3 32 Switch to s. water, reduce rate 2248 14256 1212 200 1.3 36 0 Cmt. ~ nozzle 1 2250 14256 1276 212 1.3 38 2 Pull up hole 72 fpm 3-09 WSO 5-3-98 3 Time II CTD II CTP II WHP II Rate II Vol. I Comments 3 4 2253 14039 1370 225 1.3 41 5 slow speed. Hesitate. 6 2254 13993 1414 247 1.3 43 7 Building pressure, resume 72 fpm 2255 13895 1509 326 1.3 44 8 Slowto 60 fpm 2256 13852 1569 380 1.3 45 9 Slowly building whp 10 2257 13788 1686 500 1.3 47 11 Resume 72 fpm, 2258 13736 1805 650 1.3 48 12 2259 13687 1976 837 1.3 49 13 Ramping up 2300 13650 2109 900 1.3 50 14 Crack choke & hold 900 psi 2301 13565 2386 900 1.3 51 15 2302 13520 2426 900 1.3 52 16 Some fluid to surface 2303 13456 2408 900 1.3 53 17 2304 134! 5 2461 900 1.3 54 18 2305 13374 2470 900 1.3 55 19 2306 13302 2461 900 1.3 56 20 Cmt. Away. Pull to safety 2308 13064 2490 900 1.3 60 Good fluid returns to surface. 2311 12800 2500 900 1.3 64 At safety, reduce rate & ramp 2312 12800 1300 1000 .5 65 Building whp 2314 12800 1890 1500 .5 66 2315 · 12800 1837 1500 .5 67 2 bblretumed 2316 12800 1827 1500 .5 68 2.25 returned, go to 2500 psi 2318 12800 2584 2290 .5 69 2.5 returned, little gas back 2320 12800 2880 2500 .5 70 3 returned 2322 12800 2845 2500 .5 71 3.75 returned. Ramp to 3000 psi 2324 12800 3080 2760 .5 72 4 returned, drinking a little 2325 12800 2631 2200 .5 73 4.25 returned 2327 12800 2336 2000 .5 74 5.25 returned, hesitate ~ 2000 psi 2328 12800 2362 2000 .5 75 6.25 returned. 2330 12800 2347 2000 .5 76 7.25 returned, ramp to 2500 psi 2332 12800 2770 2450 .5 78 7.5 returned 2334 12800 2849 2500 .5 79 8 returned, ramp to 3000 psi 2336 12800 2900 2575 .5 80 8.25 returned, breaking back, close chokes & trap 2400 psi 2338 12800 2300 2300 0 80 Leaking off slowly 2341 12800 2250 2250 0 80 Come on line & ramp to 2700 psi 3-09 WSO 5-3-98 4 Time Il CTD II CTP [I WHP II Rate [I Vol. II Comments 2342 12800 2882 2300 .5 81 8.5 bbls returned. Drinking some, holding 2580 psi 2344 12800 2950 2650 .5 82 8.5 returned, trap 2650 psi & hesitate. 2348 12800 2550 2600 0 82 Slowly falling off 2350 12800 2880 2575 .5 82 Ramp up 2353 12800 3144 2810 .5 83 8.75 retumed 2355 12800 3195 2860 .5 84 9.75 returned, ramp to 3000 psi 2358 12800 3226 2980 .5 85 9.875 returned 2400 12800 3300 3000 .5 86 10 returned (DATE:05-04-98) 0001 12800 3280 3000 .5 86.5 10.5 returned. Shut downpump & trap 2960 psi. 0004 12800 3150 3000 .5 86.8 Bump up & isolate from cmt. Pump. Switch to CT pump. 0010 12800 3160 3000 .5 87 Bump up to 3000 from 2925 psi 0015 12800 2888 2950 0 87 Falling off slowly. IAP up by 125 psi ? 0038 12800 2740 2750 0 87 IAP= 130psi- FLP= 330 psi 0043 12800 2800 1800 1.0 3 Bleed Whp slowly to 700 psi. meth Pump meth to Fp SQZ. Unit Line. 0056 12800 2100 700 1.15 0 Drop ball. Start Biozan. 0100 12850 3200 700 1.5 4 RIHto contaminate. 0120 3100 700 1.5 36 BIO ~ nzl. RIH ~47 FPM. 13200 0139 14021 3100 700 1.4 52 Switch to TEA. Bio 0146 14254 2950 700 .95 6 Reciprocate 3 passes 13,970'- 14,254' 0151 13960 2725 700 .92 9.6 SWITCHto slick SW. Tea 0217 14254 1650 700 1.05 26.4 TEA ~ Nzl. Lay in same. 0224 13970 1600 700 1.24 36 TEA layed in 14,254'- 13,970'. POH pumping slick SW. Slow ~ jewelry to wash clean.. 0338 8030 2080 700 1.63 160 Contaminated cement ~ surface, divert to solids tank. 0437 3000 1840 690 1.65 286 Returns clean; swap to methanol SW 0528 1000 2450 695 1.25 36 Meth. ~ Nzl. POH pumping methanol to FP from 1,000' to surface. 3-09 WSO 5-3-98 5 Time II CTD II CTP II WHP II osso] oI o 7°°I Rate II vo~o II Comments 0I 54 [ At Surface. SI Swab & Master. meth Left 700 psi on well. Fluid Summary_ BBLS Fluid 15,.2 15%/10% HCL/XYL 21 Latex Cmt 9.6 Tea 52 Biozan 525 Slick 2% KCL water 1053 SW 20 Fresh water 129 Meoh 60/40 CEMENT: Additive Concentration D020 1.000%BWOC D065 0.350%BWOC D800 0.750%BWOC M117 0.300%BWOC D047 0.100 gal/sk blend (wet) D 135 0.100 gal/sk blend (wet) D 134 1.050 gal/sk blend (wet) Weight 15.6 ppg Pv 19 ~ 170 degrees Field f/1 Test 86 cc Lab f/1 Test 74 cc Filter Cake 0.79" Lab filter cake 0.8" Thickening Time 5 hr. 40 min. 3-09 WSO 5-3-98 6 BPX Endicott Production Engineering Department DATE: 5/1/98 WELL N°: 3-09/L-28 BP EXPLORATION REP: D. Williams SERVICE COMPANY: HB&R COST CODE: N10309 DETAIL CODE: DATE/TIME 1830 · 1845 1859 1903 1905 1914 OPERATIONS SUMMARY MIRU pump, P/T hard line to 3500 psi. Start pumping diesel down I/A. @ I bpm, 375 psi. 15 bbls away, @ 3 bpm, 390 psi. 27 bbls away, @ 3 bpm, 300 ps~. Switch to seawater 6 bbls away, @ 3.6 bpm, 375 ps~. 50 bbls away, @ 4.75 bpm, 325 psi. 1925 1941 1951 1957 2O28 100 bbls away, @ 4.8 bpm, 310 psi. 175 bbls away, @ 4.75 bpm, 375 ps~. 217 bbls away, @ 3 bpm, 1500 psi. 225 bbls away, @ 1.1 bpm, 2500 psi. Shut down and monitor for 30 mins. Loss 60 psi in 30 mins. Good test. RDMO Summary: * Total of fluid pumped 27 bbls of diesel, 225 bbls of sea water. * Held on test with 2500 psi for 30 mins. Loss 60 psi. end reading 2440 psi. Bleed I/A back throughout flow line 350 psi on I/A. BPX Endicott Production Engineering Department DATE: 4~23~98 Additional Perforations (Pre-SQZ)~. x Cost Code: N10309-120 WELL N°: 3-09/L-28A Detail Code: CMT SQZ/Pre SQZ Perf/E Line BP EXPLORATION REP: D. Barba SERVICE COMPANY: SWS (Y. Morgan) DATE/TIME O930 1115 1130 1145 1200 1325 1515 1540 1545 1610 1630 1830 2030 2130 2145 2205 2215 2245 2300 0030 0230 O345 0400 0415 0445 0500 0630 0830 0930 OPERATIONS SUMMARY MIRU SWS. WHP = 450 psig, WHT = 190 deg F, lAP = 2050 psig, OAP = 200 psig, Choke = '176 Beans. Hold Safety Meeting SI Gas Lift. Choked well back to 25 beans and shut it in. Initial SIWHP = 1000 pslg. Pressure test lubricator to wellhead pressure. RIH with Gun #1 (Big Hole 20') 2 718" @ 4 SPF, 60/120 DEG PHASING AND RANDOM ORIENTATION. CCL TO TOP SHOT 7.2'. Note ran one set of rollers on bottom. Gun sat down at 8140'. For the next hour and a half or more, had to work the gun ~n the hole. The gun stopped at 9310', 10545' and 12080'. Out of the tubing tail. FLOW WELL AT 25 BEANS (without gas lift). MAKE TIE-IN PASS. MAKE +2' CORRECTION. Flag line at 14150'. PARK CCL 13962.8' AND SHOOT (TS 13970' BS 13990'). NO INDICATION. SHUT-IN WELL. POOH OOH. Confirm all shots fired. Pressure test lubricator to wellhead pressure. RIH with Gun #2 (Big Hole 30') 2 7/8" @ 4 SPF, 60/120 DEG PHASING AND RANDOM ORIENTATION. CCL TO TOP SHOT 6.3'. Note ran one set of rollers on bottom. Gun is falling fine. Out of the tubing tail. FLOW WELL AT 25 BEANS (without gas lift). Reset at Flag (+3' correction). Had to make several tie ~n pass to confirm depth. The gun and cable drag, with the stop and go motion are causing the CCL to be poor. PARK CCL 14063.7' AND SHOOT (TS 14070' BS 14100'). NO INDICATION. SHUT-IN WELL. POOH OOH. Confirm all shots fired. Pressure test lubricator to wellhead pressure. RIH with Gun #3 (Big Hole 30') 2 7/8" @ 4 SPF, 60/120 DEG PHASING AND RANDOM ORIENTATION. CCL TO TOP SHOT 6.3'. Note ran one set of rollers on bottom Out of the tubing tail. FLOW WELL AT 25 BEANS (without gas lift). Reset at Flag (+2' correction). Had to make several tie ~n pass to confirm depth. PARK CCL 13995.7' AND SHOOT (TS 14002' BS 14032'). GOOD INDICATION. SHUT-IN WELL. POOH. At surface having trouble bleeding down lubricator swab valve leaking. Off well head. Confirm all shots fired. RDMO SWS. DATE: 4-24-98 WELL N°: 3-09/L-28A TYPE OF OPERATION: OPERATIONS REPORT CONTI'''~ Additional Perforations PERFORATION SUMMARY: GUN INTERVAL SBT DEPTH FEET SUBZONE 1 13970-13990 20 2B 2 14070-14100 30 2B 3 14002-14032 30 2B All intervals were shot using 2 7/8" guns with big hole charges at 4 spf, 60/120 degree phasing and random orientation. STATE OF ALASKA .- -, ALA'~' OIL AND GAS CONSERVATION COMMI[ N REPORT SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown__ Stimulate__ Plugging__ Pull tubing__ Alter casing __ Repair well .__ Perforate X Other__ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) BP Exploration (Alaska) Inc. Development X KBE = 55.4 feet Exploratory __ 3. Address Stratigraphic 7. Unit or Property name P. O. Box 196612, Anchora.cle, Alaska 99519-6612 Service __ Duck Island Unit/Endicott 4. Location of well at surface 8. Well number 2530' NSL, 838' WEL, Sec. 8, TIIN, R17E At top of productive interval 3472' NSL, 345' WEL, Sec. 5, TIIN, R17E At effective depth 3995' NSL, 86' EWL, Sec. 4, TIIN, R17E At total depth 4056'NSL, 191'EWL, Sec. 4, T11N, R17E 3-09/L-28A SDI 9. Permit number/approval number 95-19~Not rec~uired 10. APl number 50- 029-21780-01 11. Field/Pool Endicott Field/Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 14700 feet 10287' BKB feet 14541 feet 10185' BKB feet Plugs (measured) Junk (measured) 3-3/8" Inflatable Bridge Plug (IBP) 14258'- 14266'. Length Size Cemented Measured depth True vertical depth BKB BKB 122' 30" Driven 161' 161' 2473' 13 3/8 3254 C. F. Permafrost 2512' 2488' 10481' 9 5/8" 1150 C. F. Class "G" 10520' 7919' 4449' 7" 112 C. F. Class "G" 8189' - 12638' 6803' - 9129' 2173' 5" 1095 C. F. Class "G" 12477'- 14650' 9044'- 10225' measured 12515'- 12517', 14210'- 14214; 14254'-14258', 14308'- 14312', 14360'- 14364', 14488'- 14492' (Afl Squeezed) 14034-14054; 14138'-14150', 14166'-14178', 14192'-14204; 14210'-14214'; 14220'-14258', 14266'-14292', 14481'- 14490' (AllOpen) true vertical (Subsea) 9033'-9034'; 9937'-9939;' 9961'-9963'; 9991'-9993'; 10020'-10023'; 10096'-10099' (All Squeezed) 9843'-9853; 9898'-9904'; 9913'-9919'; 9927'-9934;' 9937'-9939; 9942'-9963'; 9967'-9981'; 10091'-10098' (All Open) Tubing (size, grade, and measured depth) 4 1/2" 12.6#/ft, 13 CR tubing set at 12405' Packers and SSSV (type and measured depth) 7" packer set at 12319', 4 1/2 SSSV set at 1504' 13. Stimulation or cement squeeze summary Add Perforations (3/2/98) Intervals treated (measured) Treatment description including volumes used and final pressure O /GiiqAL 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 4283 4573 10186 0 3872 4720 9480 0 Tubing Pressure 528 499 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas__ Suspended Service 17. I hereby certify that t~ foregoin~ is true and correct to the best of my knowledge. Signed ~i~~J~ ~ Title~ni¢r T~chnical,4ssi~tantlV Form 10-40~,/Rev 06/15/88 ' Date 3/9/98 SUBMIT IN DUPLICATE BPX Endicott Production Engineering Department DATE: 3/02/98 WELL N°: 3-09/L-28A BP EXPLORATION REP: SERVICE COMPANY: OBJECTIVE: Additional Perforations D. Barba SWS (Y. Morgan) Perforate 14034-14054 (2B) DATE/TIME OPERATIONS SUMMARY 073O 0830 0900 1130 1135 1150 1200 1315 1330 1400 MIRU. Request radio silence on SDI. WHP = 450 psig, WHT = 190 deg F, lAP = 2020 psig, OAP = 200 psig, Choke = 176 Beans. SI Well. Initial SIWHP = 1000. Pressure test lubricator to wellhead pressure. RIH with Gun #1 (20') 2 718" @ 6 SPF, 60 DEG PHASING AND RANDOM ORIENTATION. CCL TO TOP SHOT 5.7'. FLOW WELL AT 40 BEANS. MAKE TIE-IN PASS. MAKE +23 ' CORRECTION. PARK CCL 14028.3' AND SHOOT (TS 14034' BS 14054). GOOD INDICATION. SHUT-IN WELL. POOH OOH. Confirm all shots fired. PUT WELL ON PRODUCTION. RDMO. PERFORATION SUMMARY: GUN INTERVAL(AlT) 1 NA SBT DEPTH FEET SUBZONE 14034-14054 20 2B All intervals were shot using 2 7/8" guns at 6 spf, 60 degree phasing and random orientation. STATE OF ALASKA ALASK'--"IL AND GAS CONSERVATION COMMISSIC .... REPORT O,-- SUNDRY WELL OPEhATIONS 1. Operations performed: Operation shutdown__ Stimulate__ Plugging__ Pull tubing__ Alter casing __ Repair well Perforate X Other__ 2. Name of Operator BP Ex/a/oration (Alaska)/nc. 3. Address P. ©. Box 196612, Anchora_(Te, Alaska 99519-6612 4. Location of well at surface 2530' NSL, 838' WEL, Sec. 8, T/IN, R17E At top of productive interval 3472' NSL, 345' WEL, Sec. 5, TIIN, R17E At effective depth 3995' NSL, 86' EWL, Sec. 4, TIIN, R17E At total depth 4056'NSL, 191'EWL, Sec. 4, T11N, R17E 5. Type of Well: Development Exploratory __ Stratigraphic Service __ 6. Datum elevation (DF or KB) KBE = 55.4 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-09/L-28A SDI 9. Permit number/approval number 95-19/Not reouired 10. APl number 50- 029-21780-01 11. Field/Pool Endicott Field/Endicott Pool 12. Present well condition summary Total depth: measured true vertical 14700 feet 10287' BKB feet Effective depth: measured 14541 feet true vertical 10185' BKB feet Plugs (measured) Junk (measured) 3-3/8" Inflatable Bridge Plug (IBP) 14258; 14266'. Casing Length Size Cemented Measured depth True vertical depth Structural BKB BKB Conductor 122' 30" Driven 161' 161' Surface 2473' 13 3/8 3254 C. F. Permafrost 2512' 2488' Intermediate 10481' 9 5/8" 1150 C. F. Class "G" 10520' 7919' Production 4449' 7" 112 C. F. Class "G" 8189'- 12638' 6803'- 9129' Liner 2173' 5" 1095 C. F. Class "G" 12477'- 14650' 9044'- 10225' Perforation depth: measured 12515'- 12517', 14210'- 14214', 14254'-14258', 14308'- 14312', 14360'- 14364',14488'- 14492'(AIl Squeezed) 14138'-14150', 14166'-14178', 14192'-14204; 14210'-14214;' 14220'-14258', 14266'-14292', 14481'. 14490', (Ail Open) true vertical (Subsea) 9033'-90347 9937'-9939'; 9961'-9963'; 9991'-99937 10020'-10023? 10096'-10099' (All Squeezed) 9898'-9904'; 9913'-9919~ 9927'-9934'; 9937'-9939', 9942'-9963'; 9967'-9981 '; 10091'- 10098' (All Open) Tubing (size, grade, and measured depth) 4 1/2" 12.6#/ft, 13 CR tubing set at 12405' Packers and SSSV (type and measured depth) 7" packer set at 12319', 4 1/2 SSSV set at 1504' RECEIVED 13. Stimulation or cement squeeze summary Add Perforations (5/8/97) Intervals treated (measured) 14138'-14150'; 14166'-14178' Treatment description including volumes used and final pressure ORIG Anch0ra,93 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure 3259 7877 5550 0 5891 4987 6643 0 Tubing Pressure 487 492 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby-certify that the f~o_re, going is tl;ue and correct to the best of my knowledge. Signed ........ ,~-~-!...~/",~/~-~' j ~-~.]'7~/~ ~(; Title ~eni~r Technical zl-~-~istant IV Form 10-40~'~,~;~/(~6/15~88 ........ Date 6/24/97 SUBMIT IN DUPLICATE BPX Endicott Production Engineering Department DATE: 5/8/97 WELL N°: 3-09/L-28A BP EXPLORATION REP: SERVICE COMPANY: Additional Perforations VARBLE SWS (PALMER) DATE/TIME OPERATIONS SUMMARY 0730 MIRU SWS 0915 Hold safety meeting. Call for radio silence 0930 Arm gun Cf 1 (12') 1005 SI well. 1018 Rih with gun Cf 1 1051 Sitting down @ 6400' md. Can't work past. Open choke to 20 beans, no luck. Stand by for pump truck. 1200 Able to work past 6400' md. Sitting down @ 7450' md (GLM Cf 2) 1300 HB&R on location. Rig up to pump in sub. Stand by for water. 1350 Water on location. 1405 Start pumping down tbg. @ 3 bpm. Tools falling good. 1500 Past 10000' md. Shut down pump. Tools stopped falling. Start pumping @ 3 bpm again. 1520 Out TT. Shut down pump. Tools stopped falling. Start pumping @ 3 bpm again. 1530 Tools sat down @ 127000' md. Increase rate to 4 bpm to get past. 1550 On btm. Shut down pump & tie in. Open choke to 30 beans & open GLT line. 1604 Tied into SBT/GR dated 5/6/95. Add 2'. Stand by to unload well. 1631 Well flowing @ 40 beans. Log into place @ 14153.5' md. Difficult to verify if on depth due to high GR counts through perforated areas. Log on up past shooting depth to 13950' md. On depth 1640 Rih & log into place. Hang CCL @ 14153.5' md (12.5' from CCL to top shot). Depths look good compared to first pass. 1650 Shoot gunCf 1 from 14166'-14178' md. Good cap break & lost approx. 100 lb. weight. 1654 Log off. Stop tools & flow well for 10 min. 1704 Shut in well & POOH. 1808 OOH 1830 All shots fired. Arm gun Cf 2 1900 Rih with gun Cf 2 (12') 2000 Sat down @ 7515' md. Start pumping down tbg. @ 3 bpm. Tools falling down hole. 2055 On btm. Shut down pump & log tie in pass. Take out 6' 2105 Open choke to 40 beans to underbalance well. 2120 Log confirmation pass. On depth. 2126 Log into place & hang CCL @ 14125.5' md (12.5' from CCL to top shot) 2130 Shoot gun Cf 2 from 14138'-14150' md. Good cap break & lost approx. 100 lbs weight. 2133 Log off. Stop tools & flow well for 10 min. 2144 Shut well in & POOH. 225O OOH 2305 Confirm all shots fired. POP to FOC 2400 RDMO ~ r' ~ r-., ~ , ,-., - PERFORATION SUMMARY: GUN DLL DEPTH FEET 1 14138'-14150' MD 12 2 14166'-14178' MD 12 DATE: OPERATIONS REPORT CONTINUED WELL N°: TYPE OF OPERATION: Additional Perforations All intervals were shot using 3-3/8" RDX deep pentetrating guns at 4 spf, 60/120 degree phasing and random orientation. Had to pump tools down hole on both runs from 7400' md. Pumped a total of 248 bbls seawater on run # 1 & 129 bbls on run # 2. All seawater was filtered to 3 microns. Page 2 95--0 I 9 9 ~: -0 19 95-~0 I 9 95, "' (3 i 9 95 ..... 0i9 95 -0 i 9 95'--0 i 9 95 .... (.3 I 9 95 .... 0 '19 95 ..... 0 i 9 9 S"~ 0 I 9 95-'- 0 '19 95'-019 95'*-019 95 ....... 019 95~-019 95--019 95 .... 0i~ A C ;-i.'. C ,C I n d 'i' v 'i' d u a 'i W ,'...:'.._ 'i '1 ,'.'~eoJog'icai Hater"ia'is .Tnven!:or',y "/' !.".._. '2.:-:, r~',, r~ : x ,.-, .' ? , ~,': FJ, AI'A T DA'FA ....F'!..US ............ , ..... ................ ~. ......... , ~,. , ......... ~ .......................................................................... GR/CCL P F C/' F' E iR F B H / P R ,C, !Z !3777-~'1a606 D I F I..../G R SE,'F/G R FZNAL , .L." 137'77 .- 14606 .~. , :-C 121(30-1,".~5 ''~1 .2:' V L) bL 1~'177 ..... J4606 "' "G R x_DL/CN/ ,,.¢ E 13777--1h. 566 G F:/' C C; L - L i 4.075~-i428!5 G R / C (".; L P f::' C / F' E R F 1.: 'i4297-.- i4452 :-L. ,1650---'i4250 PFC/F'ERF ;..E' la. 310 .... 14339 F'FC/PERF i-::' F C / F' .r.::. R F ~.L la. 2'77 .....i4.!5 i'? '3 R/' C C L. ::.I: ..... i2i40 ..... i2800 n, F/GR/FINAL P L :7;; ,/F I N A L.. L 'i2i40"'14 ~'18 .~E i4040 .... Ia510 C;N/GR/CCL G R//C: ,2: L. L BI .... & SEF'IA P L S .... P R O D F'ROD F'ROF , 1 i4100 .... 1zt51S PERF' 7(378 [' ,.ii (::j d' :' 'J ii:, ,5: !: e ; (}3/' i9/9'? IR i.i i"',,] I.:,/:,. 1' r.:.., l-;'. [!:. C '"7 D "10/9 ~: j [.14 / ..... I 04//i()/9b 1 !) .fi/' 2 '1 / 95 1 ()!~ / 27/'95 'i 0 ,h / ? 7 / 9:5 · i 04/" 2 ?./!35 'J () 4./2 ? /" 9 ~'!: i {) !!) // (3 !,1 // 9 !3 i {) 5/' i) 4/' 9 ,.5 j 0 !.) / [] LI./8 , 'j ('ii 5 "~')q. "q u: · // ... / '1. ~.~ 'j t') 5//(} 4//' .95 I [) 5/'" 0/.~-/' 9.5 i 05// J2/"95 J {.) !15 ,/ I 2//95 'j (I !:, / o !, ,,,' <:i 5 .. , ~, . , .,.. i F). 2 / ,. ''~ ii ./" 98. 'J () 1:~//0 'J/" 96 'i () 3 ,/" ('.) i/' 96 F .1" i"..I A I.. {) ~11// J 0 ,.."' 98 FIH/:',I. 03/'O'?/ri)'? "> 0/" 98 r.: 3 ,'"' . AO,3CC ~ndivid,..!ai Well DATA T DATA ..... PLUS 10 .... ~. O '7 =I--:.: O N F' l.. E T :[ O N !3, A T E ',., / :I ' 'I 't / .,/ , samp'Jes r'equir"ed? yes ,iqo; c o r"e d ? y e s no. A n a i y s i' s &.':. A iq d r" e c e i' v e ,.;::! ':?y a ~ - 'n ~-~ d e s c r" i~ p t' i o n r" ,'!.~ c e -i v ::::~ :I '? C 0 l~i H E N T S STATE OF ALASKA AL _,r,,A OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate__ Plugging.__ Pull tubing __ Alter casing __ Repair well __ Perforate X Other__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2530' NSL, 838' WEL, Sec. 8, T/IN, R17E At top of productive interval 3472' NSL, 345' WEL, Sec. 5, TIIN, R17E At effective depth 3995' NSL, 86' EWL, Sec. 4, TIIN, R17E At total depth 4056' NSL, 191' EWL, Sec. 4, T11N, R17E 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 55.4 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-09/L-28A SD/ 9. Permit number/approval number 95-19/Not required 10. APl number 50- 029-21780-01 11. Field/Pool Endicott Field/Endicott Pool 12. Present well condition summary Total depth: measured true vertical 14700 feet 10287' BKB feet Plugs (measured) 3-3/8" Inflatable Bridge Plug (IBP) 14258'- 14266'. Effective depth: measured 14541 feet true vertical 10185' BKB feet Junk (measured) Casing Length Size Cemented Measured depth True vertical depth Structural BKB BKB Conductor 122' 30" Driven 161' 161' Surface 2473' 13 3/8 3254 C. F. Permafrost 2512' 2488' Intermediate 10481' 9 5/8" 1150 C. F. Class "G" 10520' 7919' Production 4449' 7" 112 C. F. Class "G" 8189' - 12638' 6803' - 9129' Liner 2173' 5" 1095 C. F. Class "G" 12477'- 14650' 9044'- 10225' Perforation depth: measured 12515'- 12517', 14210'- 14214', 14254'-14258', 14308'- 14312', 14360'- 14364', 14488'- 14492' (Afl Squeezed) 14192'-14204'; 14210'-14214; 14220'-14258', 14266'-14292', 14481'- 14490', (All Open) true vertical (Subsea) 9009'- 9010', 9913'- 9916, 9937'- 9940', 9967'- 9970', 9997'- 9999', 10073'- 10075' (Afl Squeezed) 8988'-9905'. 9908'-9911'. 9914'-9935'. 9939'-9954'. 10068'- 10075'(Afl Ooen) Tubing (size, grade, and measured depth) 4 1/2" 12.6#/ft, 13 CR tubing set at 12405' . Packers and SSSV (type and measured depth) 7" packer set at 12319', 4 1/2 SSSV set at 1504' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 3332 5091 3609 0 462 Subsequent to operation 4453 7875 4824 0 501 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended__ Service 17. I hereby-certify thattt~e'-foregoindi¢:true and correct to the best of my knowledge. ~ .... .......~-~,~, - - - Title Senior Technical Assistant IV Date 3/7/97 Form 10-404i,~v 06/15/88 SUBMIT IN DUPLICATE Endicott Production Engineering Department ADD- PERF DATE: 1/1 0/97 WELL N-°: 3-09/I-28A BP EXPLORATION REP: SERVICE COMPANY: VARBLE SWS (BAWLUK) DATE/TIME OPERATIONS SUMMARY 0900 MIRU SWS. Hold safety meeting. 0930 Call for radio silence. Arm gun # 1 1018 SI well & RIH with gun 111 9 Sat down several time's from 7800' thru 8200' md. Work thru. .121 5 ~ Out TT. Open choke to 50 beans. Sitting down @ 13650' md. Can't work thru, pinch choke back to 20 beans. RIH 1233 Log tie in pass.Tie into DIFL dated 3/24/95. Add 4'. Open choke to 40 beans 1249 RIH & tag top of IBP. Pick up @ 14216' md. Log confirmation pass. Looks like tools are floating, take out 4'. Will try one more pass with choke open. Sat down 14250' md. 1309 Log up. Add 1.5' 131 6 Tag IBP & log up. On depth. Log into place. , 1324 Hang cci @ 14183.5' (26.5' from cci to top shot on lower gun) 1326 Shoot gun from 14210'-14214' md. Good cap break, no weight change. Log off. 1331 RIH & tag IBP. Log up. On depth. 1338 RIH & log into place. Hang cci @ 14180.5' md (11.5' from cci to top shot) 1343 Shoot upper gun from 14192'-14204' md. Good cap break, small weight change 1345 Log off. Open choke to 60 beans & flow well for 10 min. 1400 SI well & POOH. 141 5 Tools hung up @ 12730' (cci depth) POP to 60 beans; tools free. SI well & POOH. 1555 OOH. All shots fired. - 1700 RDMO. POP to FOC. PERFORATION SUMMARY: SUBZONE " DEPTH- -2B 14192'-14204' MD 12' 2 B 14210'-14214' MD 4' INTERVAL ALL PERFORATIONS WERE SHOT WITH 3-3/8 RDX DEEP PENETRATING GUNS, 4 SPF, 60/120 DEGREE PHASING, RANDOM ORIENTATION. ~eoQuest 500 W. International Airport Ro~d Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10821 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Endicott (Cased Hole) 2/25/97 Well Job # Log Description Date BL RF Sepia LIS Tape 1 - 63IT -2 2 CHEMICAL CU'I-I'ER 9 701 21 I 1 1 - 63/T -2 2 PRODUCTION PROFILE 9 70111 I 1 1-63/T-22 TUBING LEAK DETECTION 9701 I 1 I 1 4-20/M-35 SDI PRODUCTION PROFILE 9701 06 I 1 4 - 26 ! O - 34 PERFORATING RECORD 9 702 07 I 1 3- 09/L- 28 A PERFORATING RECORD 9 7011 0 1 1 ~3- 29/J- 32 JEWELRY LOG 9 701 09 I 1 3- 29/J - 32 PERFORATING RECORD 9 701 09 I 1 2-44/R- 12 M PI BRIDGE PLUG RECORD 9 70 21 7 I 1 1-17/SN-02 MPI CHEMICALCU'I-I'ER 970208 I 1 1-17/SN-02 MPI JETCU'I-fER RECORD 970126 I 1 fro. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received by: STATE OF ALASKA AL, ...,KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate__ Plugging__ Pull tubing __ Alter casing __ Repair well .__ Perforate__ Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2530' NSL, 838' WEL, Sec. 8, TIIN, R17E At top of productive interval 3472' NSL, 345' WEL, Sec. 5, TIIN, R17E At effective depth 3995' NSL, 86' EWL, Sec. 4, TIIN, R17E At total depth 4056' NSL, 191' EWL, Sec. 4, T11N, R17E 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 55.4 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-09/L-28A SDI 9. Permit number/approval number 95-19/Not required 10. APl number 50- 029-21780-01 11. Field/Pool Endicott Field/Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 14700 feet 10287' BKB feet 14541 feet 10185' BKB feet Plugs (measured) Junk (measured) Casing Length Size Cemented Measured depth True vertical depth Structural BKB BKB Conductor 122' 30" Driven 161' 161' Surface 2473' 13 3/8 3254 C. F. Permafrost 2512' 2488' Intermediate 10481' 9 5/8" 1150 C. F. Class "G" 10520' 7919' Production 4449' 7" 112 C. F. Class "G" 8189'- 12638' 6803'- 9129' Liner 2173' 5" 1095 C. F. Class "G" 12477'- 14650' 9044'- 10225' Perforation depth: 14492' (All Squeezed) 14220'-14258', 14266'-14292', 14481'-14490'(Ail Open) true vertical (Subsea) 9009'- 9010', 9913'- 9916, 9937'- 9940', 9967'- 9970', (All Squeezed) 9914'-9935'. 9939'-9954'. 10068'- 10075' (Afl O~)en) Tubing (size, grade, and measured depth) 4 1/2" 12.6#/ft, 13 CR tubing set at 12405' measured 12515'- 12517', 14210'- 14214', 14254'-14258', 14308'- 14312', 14360'- 14364', 14488'- JAN 02 1997 Packers and SSSV (type and measured depth) 7"packer set at 12319', 4 1/2 SSSV set at 1504~ Oil& Gas CoDs. CoffirllJSSion A.,_L _ 13. Stimulation or cement squeeze summary Water shut off, inflatable bridge plug set (10/30/96) from 14258'-'~g~e Intervals treated (measured) Treatment description including volumes used and final pressure 127 bbls fresh sea water, 25 bbls methanol, fswhp=500 psig 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 3261 3407 8470 0 453 3696 7027 6030 0 491 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X-" 16. Status of well classification as: Oil X Gas__ Suspended__ Service 17. I hej:e~rtify that the~t"E~g_0ing is true and correct to the best of my knowledge. Si~nea'-~---~-k-¢jj/'/ ?/~( Title Senior Technical Assistant IV Form 10-40/4c/Rev 0~/{5~8 ..... ' '~ ~ Date 12/30/96 SUBMIT IN DUPLICATE SUMMARY RIH with Baker 3-3/8" IBP, running tools and TEL. Tied in to SBT jewelery log at XN nipple and took out 29'. RIH to 12270 while pumping 200°F SW. Pumped 40 bbls of SW, dropped setting ball and displaced over goose neck with 5 bbls of methanol. Waited three hours and began inflating plug. Increased pressure 3 times over 30 mins, slacked off to confirm set, then disconnected. Could not pull off bottom. Dumped packoffs and poped well to get coil moving. TEL at XN on the way out indicated that we were on depth. FP coil while tripping to surface. i[ FLUIDS PUMPED B BLS. DESCRIPTION 127 FSW 35 METHANOL ~'" BOTTOM-HOLE ASSEMBLY #1 ITool String Descriptions O.D. I.D. Len~lth Comments TC 2.75 0.87 CHECK VALVES 3.0 1.5 DICONNECT 3.38 1.49 TEL 3.38 3.1 CIRC SUB 3 1.31 SCREEN 3 1.87 RUNNING TOOL 3 1.55 IBP 3.38 11.2 "OVERALL VALUES 3.38" 22.89' JAN 02 1997' ~ & C-,as Cons. Commi~:~ k,',chorage RECE. VSD SEP 10 1996 Oil & Gas Cons. HOWARD OKLAND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date 10 September 1996 Transmittal of Data Sent by= HAND CARRY Dear Sir/Madam, Enclosed, pleaae find the data as deacribed below= ~' Oq'-~ 2-68/s-17 ~ 2-68/S-17 %~-i%q 1-35/O-25 (ap'r) <~ 7' 03%3-21/L-34 (SDI) '~ ~-21/L-34 (SDI) ~q, OO~ ~-~/=-== ~. ~% ~-0s/.-=~ 3-47/Q-35 (SDI) 3-47/Q-35 (SDI) g%' O~ '~ 4-26/0-34 4-26/0-34 ~E, ~t~ 3-0~/~-28~ ~n~/ · DESCRIPTION i PLS FINAL BL+RF I PFC/PERF FINAL BL+RF 1 PLS FINAL BL+RF I PFC/PERF FINAL BL+RF I PFC/PERF FINAL BL+RF 1 PLS FINAL BL+RF i PLS FINAL BL+RF I PLS FINAL BL+RF i PFC/PERF FINAL BL+RF I PLS FINAL BL+RF i PLS FINAL BL+RF 1 PFC/PERF FINAL BL+RF I PFC/PERF FINAL BL+RF I PFC/PERF FINAL BL+RF i PFC/PERF FINAL BL+RF I PLS FINAL BL+RF Run ~ i Run · i Run · I Run · i Run · i Run · i Run · I Run · i Run · i Run · i Run · i Run · I Run · i Run · 1 Run · 1 Run · i ECC No. 5639.03 5639.04 5692.03 5725.07 5765.12 5765.11 5958.03 5959.06 5961.04 6006.08 6034.08 6034.07 6034.09 6355.11 6355.10 6397.15 STATE OF ALASKA AL, ._,~,A OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate__ Plugging.__ Pull tubing__ Alter casing __ Repair well .__ Perforate X Other~ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2530' NSL, 838' WEL, Sec. 8, TIIN, R17E At top of productive interval 3472' NSL, 345' WEL, Sec. 5, TIIN, R17E At effective depth 3995' NSL, 86' EWL, Sec. 4, TIIN, R17E At total depth 4056' NSL, 191' EWL, Sec. 4, T11N, R17E 5. Type of Well: Development Exploratory Stratigraphic Service ORIGINAL 6. Datum elevation (DF or KB) KBE = 55.4 feet 7. Unit or Properly name Duck Island Unit/Endicott 8. Well number 3-09/L-28A 9. Permit number/approval number 95-19/Not required 10. APl number 50- 029-21780-01 11. Field/Pool Prudhoe Off Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 14700 feet 10287' BKB feet 14541 feet 10185' BKB feet Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth BKB BKB 122' 30" Driven 161' 161' 2473' 13 3/8 3254 C. F. Permafrost 10481' 4449' 2173' 2512' 2488' 9 5/8" 1150 C. F. Class "G" 10520' 7919' 7" 112 C. F. Class "G" 8189'- 12638' 6803'-9129' 5" 1095 C. F. Class "G" 124 77' - 14650' 9044' - 10225' measured true vertical 12515'- 12517', 14210'- 14214', 14254'-14258', 14308'- 14312', 14360'- 14364', 14488'- 14492' (All Squeezed) 14220'-14258', 14266'-14292', 14481'- 14490' (Afl Open) (Subsea) 9009'- 9010', 9913'- 9916, 9937'- 9940', 9967'- 9970', 9997'- 9999', 10073'- 10075' (All Squeezed) 9914'.-9935'. 9939'..9954'. 10068' - 10075' (Afl Ooen) Tubing (size, grade, and measured depth) 4 1/2" 12.6#/fl, 13 CR tubing set at 12405' Packers and SSSV (type and measured depth) 7" packer set at 12319', 4 1/2 SSSV set at 1504' RECEIVED 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure AUG 1 2 1996 Alaska Oil & Gas Cons. Commission Anchorage 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 4159 5112 6785 0 5423 6568 6366 0 461 497 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify th.at t~going is true and correct to the best of my knowledge. Form 10-404 I~/ev 06/15/88 Date 8/9/96 SUBMIT IN DUPLICATE Endicott Production Engineering Department ADD - PERFS DATE: 2/1 7~96 WELL N°: 3-09/L-28A BP EXPLORATION REP: SERVICE COMPANY: VARBLE AWS (HARPER) DATE/TIME OPERATIONS SUMMARY 2/17 1200 MIRU ATLAS 1330 RIH WITH GR/CCL/GUN # 1 (26') 1500 TIE INTO DIFL DATED 3/24/95 ADD 14' &FLAG LINE 1520 LOG CONFIRMATION PASS - ON DEPTH - LOG INTO PLACE. 1530 HANG CCL @ 14264' MD (2' FROM TOP SHOT) & SHOOT GUN # 1 FROM 14266' - 14292' MD - LOG OFF. GOOD CAP BREAK, NO WEIGHT LOSS. 1545 POOH 1640 OOH - ALL SHOTS FIRED. 1800 RD ATLAS - RETURN WELL TO PRODUCTION 2/18 0800 RIG UP ATLAS 0900 RIH WITH GR/CCL/GUN # 2 (20') 1030 VERY SLOW GOING IN HOLE. CAN'T GET PAST 10500' MD 1100 POOH 1220 OOH . ADD 2 - 3.5" BY 3' SINKER BARS 1300 RIH WITH NEW TOOL STRING & GUN # 2 1445 ABLE TO GET DOWN HOLE. TIE IN. TAKE OUT 2'. LOG INTO PLACE 1500 HANG COL @ 14236' MD(2' FROM TOP SHOT) SHOOT GUN # 2 FROM 14238' - 14258' MD. GOOD CAP BREAK, NO WEIGHT LOSS. 1515 POOH 1610 OOH - ALL SHOTS FIRED 1645 RIH WITH GUN # 3 (18') 1700 LOST SIGNALTO TOOLS @ APPROX, 1200' MD. POOH 1715 OOH. CONDUCTOR WIRE BROKE @ CABLE HEAD. STAND BY TO RE-HEAD 1800 RIH WITH GUN # 3. LOST TOOL SIGNAL @ APPROX. 1200' MD. PULL UP HOLE & RE-GAIN SIGNAL, APPEARS TO BE WORKING OK, RIH, 2050 TIE IN & LOG INTO PLACE. 2105 HANG CCL @ 14216' MD (4' FROM TOP SHOT) SHOOT GUN # 3, NO CAP BREAK 2115 POOH 2210 OOH. GROUND WIRE ON GUN BROKE. REPLACE WIRE & EBW PACKAGE 2300 RIH WITH GUN # 3 2315 LOST SIGNAL TO TOOLS. POOH 2230 OOH. INTERMITANT SHORT IN BTM. SINKER BAR. 2/19 0020 RIH WITH 1 SINKER BAR/GR/CCL/GUN # 3 (18') 0150 TIE IN & LOG INTO PLACE. 0205 HANG CCL @ 14216' MD (4' FROM TOP SHOT) SHOOT GUN #3 FROM 14220' - 14238' MD. GOOD CAP BREAK & SLIGHT WEIGHT LOSS 0215 POOH 0320 OOH. ALL SHOTS FIRED. 0400 RDMO ATLAS. POP TO TEST SEPERATOR PERFORATION SUMMARY: SUBZONE DEPTH FEET 2B 14266' - 14292' 26' 2B 14220'- 14258' 38' ALL PERFORATIONS WERE SHOT BALANCED BECAUSE OF TOOLS BEING BLOWN UP HOLE TRYING TO UNDER BALANCE WELL. ALL PERFORATIONS WERE SHOT USING 3 3/8 ALPHA JETS, 6 SPF, 60 DEG. PHASING & RANDOM ORIENTATION LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 7 March 1996 Transmittal of Data ECC #: 6397.12 Sent by: HAND CARRY Data: LDWG Dear Sir/Madam, Reference: BP 3-09/L-28A ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 LDWG TAPE+LIS Run # 1 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 ~ Anchorage, AK 99518 .~to (907) 563-7803 Received by:. Date: MAR 20 1998 Alaska Oil & Gas Oons, Commission Anchorage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 995011 Date: 17 February 1996 Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 1 PLS FINAL BL+RF 1 PDK FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 CN FINAL BL+RF Run # 1 Run $ 1 Run # 1 Run # 1 ECC No. 5723.10 5945.02 6185.14 6397.12 ..--Please sign and return to: Attn. Rodney D. Paulson ...................... Western Atlas Logging Services 5600 B Street Suite 201 -~ Anchorage~ AK 99518 Received by: ' , Date: STATE OF ALASKA AL. _,,~A OIL AND GAS CONSERVATION COMMISSIL~N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate__ Plugging__ Pull tubing __ Alter casing __ Repair well __ Perforate X Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2530' NSL, 838' WEL, Sec. 8, TIIN, R17E At top of productive interval 3472' NSL, 345' WEL, Sec. 5, TIIN, R17E At effective depth 3995' NSL, 86' EWL, Sec. 4, TIIN, R17E At total depth 4056' NSL, 191' EWL, Sec. 4, T11N, R17E 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 55.4 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-09/L-28A 9. Permit number/approval number 95-19/Not required 10. APl number 50- 029-21780-01 11. Field/Pool Prudhoe Off Pool 12. Present well condition summary Total depth: measured true vertical 14700 feet 10287' BKB feet Plugs (measured) Effective depth: measured true vertical 14541 feet 10185' BKB feet Junk (measured) Casing Length Structural Conductor 122' Surface 2473' Intermediate 10481' Production 4449' Liner 2173' Perforation depth: Tubing (size, grade, and measured depth) Size Cemented Measured depth True vertical depth BKB BKB 30" Driven 161' 161' 13 3/8 3254 C. F. Permafrost 2512' 2488' 9 5/8" 1150 C. F. Class "G" 10520' 7919' 7" 112 C. F. Class "G" 8189'- 12638' 6803'- 9129' 5" 1095 C. F. Class "G" 12477'- 14650' 9044'- 10225' measured 12515'- 12517', 14210'- 14214', 14254'-14258', 14308'- 14312', 14360'- 14364', 14488'- 14492' (All Squeezed) 14481'- 14490' (Open) true vertical (Subsea) 9009'- 9010', 9913'- 9916, 9937'- 9940', 9967'- 9970', 9997'- 9999', 10073'- 10075' (All Squeezed) 10068'- 10075' (Ooen~ 4 1/2" 12.6#/ft, 13 CR tubing set at 12405' Packers and SSSV (type and measured depth) 7" packer set at 12319', 4 1/2 SSSV set at 1504' 13. Stimulation or cement squeeze summary Addperfs 10/17/95 and scale inhibitor treatment performed on 12/23/95. Intervals treated (measured) 14210'- 14214', 14308'- 14312', 14481'- 14490' Treatment description including volumes used and final pressure 13 Bbls seawater/mutual solvent, 235 Bbls seawater/scale inhibitor mix, 148 Bbls seawater/2% surfactant, 218 Bbls seawater tubing volume and $ Bbls methanol FWSHP = 1000 psig 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 3180 3079 4770 0 2430 1785 5164 0 Tubing Pressure 613 574 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas__ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-4<~4 Rev 06/15/88 Date SUBMIT IN DuPLiCATE Endicott Production Engineering Department DATE: 10/17/95 WELL N-°: 3-09/L-28A BP EXPLORATION REP: SERVICE COMPANY: Additional Perforations POWERS ATLAS (BARBA) IiDATE/TIME OPERATIONS SUMMARY I 1300 MIRU AWS. INSTALL SSV FUSIBLE CAP. FWHP = 400 PSI; lAP = 1400 PSI, OAP= 400 PSI, WHT=180°F. 1400 SI WELL. PRESSURE TEST LUBRICATOR TO SIWHP. 14:08 RIH WITH GUN #1 (9 FT WITH SKATES TOP AND BOTTOM 23' OVERALL LENGTH). 14:50 SAT DOWN AT 8300' TRY TO WORK DOWN. 15:45 CANT GET PAST 10580. STANDBY FOR PUMP TRUCK. SIP=1000 PSI 17:25 HB&R ON LOCATION. RU AND PUMP AT 3-4 BPM. 17:36 TOOL STRING IS MOVING. 17:58 STOP PUMPING AFTER83 BBLS OF SW AWAY. AVERAGE PUMP PRESSURE WAS 1000 PSIG. FINAL WHP AFTER PUMPING WAS 200 PSIG. 18:01 ON BOTTOM - OPEN WING VALVE AND SET CHOKE AT 50 BEANS AND TURN ON GASLIFT TO UNLOAD THE WATER. 18:24 TIE INTO DIL DATED 3/24/95 AND MAKE A -2 FT CORRECTION. 18:50 HANG CCL AT 14478 (3' TO TOP SHOT). SHOOT GUN #1 FROM 14481' - 14490'. LOST 200 LBS. LOG OFF. 1 9:00 SI WELL AND POOH. 20:12 AT SURFACE. BLEED LUBRICATOR & CONFIRM ALL SHOTS FIRED. 20:36 POP WELL FROM SIP=1250. RDMO ATLAS PERFORATION SUMMARY' GUN DLL DEPTH FEET SUBZONE I 14481' - 14490' 9 2A All intervals were shot using 3-3/8" Alpha Jet guns at 6 spf, 21 gram charges, 60 degree phasing and random orientation. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG REVISION - 01/05/96 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration 95-19 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 5o- 029-21780-01 4. Location of well at surface 9. Unit or Lease Name 2530' NSL, 838' WEL, SEC. 8, T11N, R17E ' .. -, ........4_ Duck Island Unit/Endicott .(;,,., ....... 10. Well Number At Top Producing Interval ~-.~.4~,~ ~,~.'~ :.. ~,,'..,.,. ! ........... · = :~.~¢~ ........ '~ 3-09/L-28A SDI At Total Depth i : ' 1Endicott1. Field and Pool Field/Endicott Pool 4056' NSL, 191' EWL, SEC. 4, T11N, R17E "~'~";."-;.' - -~' 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 79.4 ADL 047503 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 03/10/95 03/21/95 04/29/95I 6'- 12' feet MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 14700'MD/10287'TVD 14541'MD/10185'TVD YES [] NO []I 1504 feet MD I 1465'(Approx.) 22. Type Electric or Other Logs Run CHT, GR, CN, TEMP, ZDL, DIEL, RD, DIFL 23. CASING, LINER AND CEMENTING RECORD SE'I-FING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP DO'FI'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" Structural Drive Pipe Surface 161' Drive 13-3/8" 68# L-80 Surface 2512' 17-1/2" 3254 Cu. Ft. Permafrost 9-5/8" 47# NTSOS Surface 10520' 12-1/4" 1150 Cu. Ft. Class 'G' 7" 26# L-80 8189' 12638' 8-1/2" 112 Cu. Ft. Class 5" 18# L-80 12477' 14650' 8-1/2" 1095 Cu. Ft. Class 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" Gun Diameter, 6 spf 4-1/2" 12405' 12318' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12515'- 12517' 9086'- 9087' Sqzd DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 14210'- 14214' 9993'-9995' 12515'- 12517' 89 Cu. Ft. Class 'G' Sqzd to 1500psi 14254'- 14258' 10017'- 10019' 14308'- 14312' 10047'- 10049' 14488'- 14492' & 14360'- 14364' 10077'- 10079' Sqzd 14360'- 14364' 84 Cu. Ft. Class 'G' Sqzd to 1350psi 14488'- 14492' 10152'- 10155' Sqzd Freeze Protected w/Diesel to 1500' 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) May 8, 1995 I Flowing Date of Test Hours Tested PRODUCTION FOR OlL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO ]'EST PERIOD ~ I Flow Tubing Casing Pressure CALCULATED OlL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, aoparent dips, and presence of oil, gas or water. Submit core chips. RECEIV u JAN 0 9 t995 Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Kekiktuk 13938' 9848' K2A 14304' 10038' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge /I '~,_-~,..,{~ / /~_~~ Senior Drilling Engineer Signed _. '~ / - Title Date ,.' INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, G~$ Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. RECEtV L) Item 28: If no cores taken, indicate "none". Form 10-407 /~aska Oil & Gas Cons, Commission Anchorage WELL : SDI 3-09 OPERATION: RIG : DOYON 15 PAGE: 3 03/05/95 (11) TD:10520' ( 0) 03/06/95 (12) TD:10520' ( 0) 03/07/95 (13) TD:10520' ( 0) 03/08/95 (14) TD:10520' ( 0) RIH W/DRILLING ASSY MW: 0.0 VIS: 0 CUT DL. RIH W/MILLING ASSY (SLM). REV CIRC EVERY 20 STNDS T/CLEAR DP. MILL OUT CMT & JUNK F/10311 T/10500. HARD CMT F/10388. CIRC & RECIP ROTATING PIPE UNTILL THE RETURNS ARE CLEAN. DROP DP WIPER & PUMP T/BTTM. POOH. CLEAN JUNK BASKETS. RECOVERED 12 LBS OF METAL. LD MILLING ASSY. PU DRILLING BHA & ORIENT. TEST MWD. RIH W/DRILLING ASSY. POOH CHK F/WASH OUT MW: 0.0 VIS: 0 DRILL OUT CMT F/10500 T/10517. MOTOR STALLED. PU T/10400. UNABLE T/GO DOWN W/50K WT. POOH T/9940. HAD 50K OVER PULL T/10230. POOH. CHANGE OUT MOTOR. LD BIT. TEST MWD & ORIENT. PU 8.5" MILL ON DRILLING ASSY. SERVICE RIG. RIH T/5000. CUT DL. RIH T/10514. MILL JUNK & CMT T/10519. OBSERVE 400 PSI DROP IN PRESS. CHECK F/WASH OUT. 40K OVER PULL OFF BTTM. T/10400. RIH W/REV CIRC JUNK BASKET MW: 0.0 VIS: 0 POOH & CHECK F/LEAK, OK. LD MOTOR. PU NEW BHA W/MILL. CIRC THRU JARS, CHECK F/LEAKS, OK. SERVICE TOP DRIVE, CHANGE OUT LINK TILT CATCHER. RIH T/10519. DRILL W/MILL F/10519 T/10540. LAST 3' APPEARED T/BE IN THE FORMATION. CIRC WHILE ROTATING & RECIPROCATING HOLE CLEAN. OBSERVE THE WELL. POOH. OVER PULL DRAG CONSTANTLY UNTIL 70 STNDS OUT @ 3858. LD MILL. CLEAN JUNK BASKETS, RECOVERED 50 LBS OF METAL & CLAY F/FORMATION. TEST BOPE T/5000. WITNESS OF TEST WAS WAIVED BY D. AMOS, AOGCC REP. SERVICE THE RIG. MU REV. CIRC JUNK BASKET ON DP & RIH. POOH W/JUNK BASKET MW: 0.0 ViS: 0 RIH W/REV CIRC JUNK BASKET. CUT DL. RIH REV. CIRC @3800, 6200 & 8580. REV CIRC, WORK PIPE DOWN, TAG UP @ 10509. WORK T/10516 W/1000PSI. POOH, REV. CIRC @ 10460 & 7540. PRESS RIG UP SHOWING BASKET FULL OF JUNK. POOH. CLEAN OUT JUNK BASKET & RECOVERED 59 LBS OF METAL JUNK. RIH W/JUNK BASKET T/10516. STRIP IN, REV. CIRC @ 1500 PSI. F/10516 T/10540. BASKET PACKED OFF W/JUNK. POOH. WELL : SDI 3-09 OPERATION: RIG : DOYON 15 PAGE: 4 03/09/95 (15) TD:10520' ( 0) 03/10/95 (16) TD:10620' ( 100) 03/11/95 (17) TD:10990' ( 370) 03/12/95 (18) TD:ll189' ( 199) 03/13/95 (19) TD:11857' ( 668) POOH W/JUNK BASKETS Nf~: 0.0 VIS: 0 POOH W/JUNK BASKETS. RECOVERED 251 LBS OF METAL CUTTINGS F/FINGER BASKET. RIH W/JUNK BASKETS. BREAK DOWN JTS IN MIDDLE OF STANDS, CHECK F/JUNK. CUT DL. SERVICE & INSPECT TOP DRIVE. RIH W/JUNK BASKET T/10524. BREAK DOWN EA. STNAD. CHECK F/METAL CUTTINGS. RIVERSE CIRC. F/10524 T/10542. PACKED OFF JUNK BASKETS. POOH WET W/JUNK BASKETS. CLEAN & EMPTY BASKETS, RECOVERED 209 LBS. (188 LBS METAL & 21 LBS CLAY). RIH W/JUNK BASKETS T/10540. REVERSE CIRC 10540 T/10544. POOH WET W/JUNK BASKETS. TRIP F/BHA MW: 0.0 VIS: 0 POOH WET W/JUNK BASKETS. CLEAN JUNK BASKETS. RECOVERED 29 LBS OF METAL CUTTING. MU BHA #4 & ORIENT. TIH T/500. TEST MWD & MOTOR. TIH T/4300. CUT & SLIP DL. SERVICE TOP DRIVE. TIH T/10500. ORIENT MOTOR. TIME DRILL F/10539 T/10572. SLIDE F/10572 T/10620. BTTM OF WINDOW IS 10570. CUTTINGS RETURNS HAD MOSTLY SAND & SHALE & VERY LITTLE CMT. CBU. OBSERVE WELL & TRIP OUT OF HOLE F/BHA. DRILLING MW: 0.0 VIS: 0 TOOH F/BHA. MU BHA #5. TIH T/10500. FLOW TEST MOTOR & MWD @600'. ORIENT & TRIP IN HOLE T/10605. NO PROBLEMS GOING OUT THE WINDOW. DRILL F/10620 T/10922. 30' SURVEYS. CIRC HIGH & LOW VIS SWEEPS AROUND. TOOH T/10520. WIPER TRIP. SERVICE TOP DRIVE. TOOL FACE & TIH T/10922. NO PROBLEMS. DRILL F/10922 T/10997. DRILLING MW: 0.0 VIS: 0 DRILL F/10997 T/ll130. SLIDING 4 HRS. ROTATING .5 HRS. CIRC SWEEPS AROUND. OBSERVE THE WELL. BREAK OUT TOP DRIVE. TOP DRIVE IS FROZEN DUE T/-47 DEGREE AMBIENT TEMP. TOOH & BREAK OUT BIT. MU BIT & BHA & TIH T/4412. CUT DL. FILL DP. SERVICE TOP DRIVE. TIH T/10520. ORIENT TOOL FACE @ WINDOW & TIH T/ll130. NO PROBLEMS. THAW TOP DRIVE. TEMP IS NOW -53 DEGREES. DRILL F/ll130 T/11189. DRILLING MW: 0.0 VIS: 0 DRILL F/11189 T/11567. CHECK FLOW & SHORT TRIP T/10519. NO PROBLEMS. SHUT DOWN #1 & #2 TRUBINES & CHANGE HUFF & PUFF FILTERS ON INTAKE DUE T/THE SEVERE ICE CONDITIONS. TURBINE #3 IS DOWN F/MAINTENANCE. TIH T/11567. OK. ORIENT TOOL FACE & DRILL F/11567 T/11857. WELL : SDI 3-09 OPERATION: RIG : DOYON 15 PAGE: 5 03/14/95 (20) TD:12096' ( 239) 03/15/95 (21) TD:12565' ( 469) 03/16/95 (22) TD:13203' ( 638) 03/17/95 (23) TD:13305' ( 102) 03/18/95 (24) TD:13900' ( 595) 03/19/95 (25) TD:14101' ( 201) 03/20/95 (26) TD:14394' ( 293) TRIP IN HOLE MW: 0.0 VIS: 0 DRILL F/ 11857 - 12096'. CIRCULATE LOW/HIGH VIS SWEEPS. TRIP OUT OF HOLE. CHECK SHOT SURVEYS @ 11819, 11787 AND 11218' PUMPED DRY JOB AFTER PULLING IN TO 9 5/8" CASING. PULL BHA AND LAY DOWN MWD. BOPE TEST. MAKE UP BHA #7. ORIENT TOOL FACE. TEST MWD. TRIP IN HOLE. DRILLING MW: 0.0 VIS: 0 TRIP IN HOLE TO 12096', WASHED THROUGH TIGHT SPOT @ 11645'. DRILL AND SURVEY F/ 12096 - 12565'. DRILLING MW: 0.0 VIS: 0 DRILL AND SURVEY F/ 12565 - 13105'. CIRCULATE SWEEPS AROUND. SHORT TRIP TO 12045'. TRIP IN HOLE TO 13105'. PICKED UP 12 JTS OF 5" DRILL PIPE. NO PROBLEMS. DRILL AND SURVEY F/ 13105 - 13203'. TRIP IN HOLE MW: 0.0 VIS: 0 DRILL AND SURVEY F/ 13203 - 13305' CIRCULATE LOW AND HIGH VIS SWEEPS. TRIP OUT OF HOLE TO BHA. NO PROBLEMS. PULL BHA. LAY DOWN MWD, MOTOR AND BIT #5. MAKE UP BHA #6. NEW MWD, MOTOR AND BIT. ORIENT AND TEST MWD. TRIP IN HOLE WITH DRILL PIPE. CUT AND SLIP DRILLING LINE. TRIP IN HOLE. PICKED UP 18 JTS FROM PIPE SHED FOR TOP DRIVE. TRIP MW: 0.0 VIS: 0 TRIP IN HOLE TO 13305' WASH TIGHT HOLE @ 12960'. BENCHMARK SURVEY @ 130i8'. CIRCULATE OUT FOAMED UP MUD @ REDUCED RATE. QUITE A BIT OF AIR IN MUD FROM FILLING DRILL PIPE WHILE TRIPPING IN HOLE. DRILL AND SURVEY F/ 13305 - 13900' CIRCULATE LOW AND HIGH VIS SWEEPS AROUND. TRIP OUT OF HOLE FOR BHA. WILL LAY DOWN MWD AND MOTOR BEFORE DRILLING PRODUCTION ZONES. DRILLING MW: 0.0 VIS: 0 TRIP OUT OF HOLE TO BHA. PULL BHA. LAY DOWN MWD, MOTOR, BUMPER SUB AND BIT. MAKE UP BHA #7 AND BHA #9. TRIP IN HOLE TO 10500'. CIRCULATE OUT AIREATED MUD. MUD WT CUT TO 8.9 PPG. TRIP IN HOLE. TIGHT HOLE AT 13650'. REAM TIGHT HOLE FROM 13650 - 13900'. DRILL F/ 13900 - 14101'. TRIP IN HOLE MW: 0.0 VIS: 0 DRILL F/ 14101 - 14394' CIRCULATE BOTTOMS UP. OBSERVE WELL. TRIP OUT OF HOLE. HOLE TIGHT FIRST 3 STANDS. PULL BHA, CHANGE BIT AND RIH W/ BHA. TRIP IN HOLE. CUT DRILLING LINE. TRIP IN HOLE TO 10500' WELL : SDI 3-09 OPERATION: RIG : DOYON 15 PAGE: 6 03/21/95 (27) TD:14700'( 306) 03/22/95 (28) TD:14700' ( 0) 03/23/95 (29) TD:14700' ( 0) CIRCULATING MW: 0.0 VIS: 0 TRIP IN HOLE TO 10520'. CIRCULATE AERATED MUD OUT OF HOLE @ 10520' TRIP IN HOLE TO 13625'. REAM AND WASH FROM 13625 - ~4394' HOLE WAS TIGHT AND PACKING OFF FROM 13650 - 13800'. DRILL FROM 14394 - 14700' CIRCUALTE LOW AND HIGH VIS SWEEPS. WIPER TRIP 12 STANDS. TIGHT HOLE. PUMPED OUT OF HOLE FROM 14415 - 14005' AND 13815 - 13625' REAMED OUT TIGHT SPOTS. TRIP IN HOLE TO 14700'. NO PROBLEMS. CIRCUALTE SWEEPS. RIG REPAIR MW: 0.0 VIS: 0 CIRC & CONDITION MUD T/10.4 PPG. HI-LO SWEEPS. WIPER TRIP IN T/9-5/8" CASG. NO PROBLEMS. HOLE LOOKING GOOD. REPAIR BEARINGS IN DYNAMATIC BRAKE. NEW BEARINGS DUE T/ARRIVE THIS AFTERNOON. CBU EVERY 12 HOURS. RIG REPAIR RIG REPAIR, WORK ON DYNA-MATIC. MW: 0.0 VIS: 0 03/24/95 (30) TD:14700' ( 0) 03/25/95 (31) TD:14700' ( 0) 03/26/95 (32) TD:14700' ( 0) WL LOGGING MW: 0.0 VIS: 0 RIG REPAIR, WORK ON DYNA-MATIC. POOH W/10 STNDS OF DP. CHECK DYNA-MATIC. OK. RIH T/12474. CBU. NO CUTTINGS IN RETURNS. MUD VIS @200. RIH T/TD @14700. NO FILL ON BTTM. CBU W/HI & LO VIS SWEEPS. SHORT TRIP--15 STNDS F/14700 T/13275. OK. DROP MULTI-SHOT SURVEY. POOH. LD SURVEY TOOL. RU ATLAS W/L, RIH W/LOGGING TOOLS. PIPE CONVEYED LOGGING MW: 0.0 VIS: 0 RIH W/ATLAS WL T/LOG. UNABLE T/WORK TOOLS BELOW 13650. POOH. RD ATLAS WL TOOLS. RU PIPE CONVEYED LOGGING TOOL. LOAD SOURCE. RIH W/DP T/5335. CUT DL. RIH T/13656 W/PIPE CONVEYED LOGGING TOOLS ON DP. PU SIDE ENTRY SUB, RIH W/WL, PRESS T/1600PSI T/LATCH WET CONNECTOR. INSTALL CABLE CLAMP ON WL. LOG F/13800 T/14677. POOH T/13850. LOG T/14400. LOG OUT T/13800. RIH F/WIPER TRIP MW: 0.0 VIS: 0 POOH W/WL. RD SIDE ENTRY SUB. OBSERVE WELL. POOH W/59 STDS OF DP. LD EXCESS DP (16 STNDS). REPAIR PIPE SKATE CHAIN. POOH W/DP & CONVEYED WL LOGS. REMOVE THE SOURCE. PULL WEAR RING. TEST BOPE. INSTALL WEAR RING. PU BHA & RIH T/5300. REPAIR IRON ROUGHNECK & SERVICE THE TOP DRIVE. RIH & CLEAN OUT T/TD.@14700. WELL : SDI 3-09 OPERATION: RIG : DOYON 15 PAGE: 7 03/27/95 (33) TD:14700' ( 0) 03/28/95 (34) TD:14700' ( 0) 03/29/95 (35) TD:14700' ( 0) 03/30/95 (36) TD:14700' ( 0) RIH W/7" LINER MW: 0.0 VIS: 0 RIH W/WIPER, WASH LAST 90' T/BTTM. NO FILL. CIRC HOLE CLEAN W/LO/HI VIS SWEEPS. POOH & LD BHA. WAIT ON 7" CROSS OVERS(3) F/THE MACHINE SHOP. RIH W/109 JTS OF 7" LINER. FILL EVERY JOINT W/MUD. PU LINER HANGER. CIRC. WHILE CLEARING FLOOR OF CASING RUNNING TOOLS. RIH W/7" LINER ON DP. HANGING WT OF 109 JTS OF 7" LINER =175,000#. CIRC' & COND HOLE FLUID MW: 0.0 VIS: 0 RIH W/109 JTS OF 7" LINER ON 5" DP. 7" LINER GOT STUCK @12638. 2118' BELOW THE SECTION WINDOW @ 10520.WORK PIPE T/FREE LINER, CIRC LO/HI VIS SWEEPPS @2000PSI, 5 BPM. PIPE PACKED OFF & LOST RETURNS, 150 BBLS MUD. OBSERVE WELL, WELL IS FLOWING 38 BBLS PIT GAIN. SHUT WELL IN & MONITOR GUAGES. CASING PRESSURE IS 1350PSI. PUMPED DOWN DP, NO RETURNS ON CASG. PRESS BROKE OVER @ 1750PSI & PUMPED AWAY T/FORMATION. 35 BBLS/6BPM. RU T/BLEED PRESSURE F/CASG THRU CHOKE T/TRIP TANK. GRADUALLY BLEED PRESS OFF CASG. RECORDING PRESS DROPS PER BBLS GAIN TILL ALL THE PRESS IS OFF THE CASG. OPENED BOP & MONITOR THE WELL. RELEASED F/7" LINER DP. CIRC & COND HOLE FLUID ABOVE LINER TOP @ 8181 SHUT PUMP OFF @0530 HRS & MONITOR WELL 2 BBLS/HR FLOW. PULL OUT OF HOLE MW: 0.0 VIS: 0 OBSERVE WELL. FLOWING BACK MUD F/CHARGED FORMATION @ 2 BPM. CIRC. 11.1 PPG MUD. OBSERVE WELL, STILL FLOWING. CIRC. 11.4 PPG MUD. OBSERVE WELL--STILL FLOWING @ 1BPM. CIRC 11.7 PPG MUD, CUT PUMP RATE BACK T/3BPM T/KEEP F/PUMPING AWAY MUD. OBSERVE THE WELL, NO FLOW BACK. POOH & LD EXCESS DP. RIH W/CMT STINGER MW: 0.0 VIS: 0 POOH LD EXCESS DP & TIW HANGER SETTING TOOL. RU ATLAS WL. RIH W/7" CMT RET ON "E" LINE, SET RET @ 12540' = 10' ABOVE L-COLLAR. RU SHOOTING FLANGE, RISER & LUBRICATOR, TEST. RIH W/PERF GUNS ON "E" LINE, PERF 12 HOLES IN THE 7" LINER @12.515 T/12517. POOH W/"E" LINE, RD ATLAS, SHOOTING FLANGE & RU FLOW LINE. SERVICE THE RIG . RIH W/HALLIBURTON STINGER, PU 3.5" DP, 141 JTS, STRAP & RABBIT DP. CUT DL. RIH W/5" DP (SAM) . WELL : SDI 3-09 OPERATION: RIG : DOYON 15 PAGE: 8 03/31/95 (37) TD:14700' ( 0) 04/01/95 (38) TD:14700' ( 0) 04/02/95 (39) TD:14700' ( 0) 04/03/95 (40) TD:14700' ( 0) 04/04/95 (41) TD:.14700' ( 0) POOH MW: 0.0 VIS: 0 STING INTO CMT RET. ESTAB. CIRC, TEST CMT LINES T/3000PSI. PUMP 10 BBLS WATER, 20 BBLS OF 16 PPG CMT, 5 BBLS WATER, DISPLACE W/RIG PUMP @ 3 BPM, 1200 PSI. GOOD CIRC. 8.6 BBLS OF CMT & 11.4 BBLS IN 307' INSIDE THE 7" LINER. UNSTUNG F/RET. PULL OUT W/10 STNDS. OF DP. REV CIRC @1000PSI. SQUEEZE CMT T/PERFS, 6 BBLS SQUEEZED, OBSERVED THE WELL. POOH W/75 STDS. WELL BLEEDING OFF CHARGED PSI, 5 BBLS. MUD. OBSERVED THE WELL--STABLE. NO FLOW BACK. POOH LD CMT RETAINER. RIH W/TIW LINER TOP PACKER T/8050, TWO STNDS ABOVE 7" LINER. WOC, PU & STRAP NEXT BHA, CHANGE LINER & SWAB IN #1 PUMP, WHILE WOC. TAG LINER TOP @ 8196, ENGAGE SEALS INTO LINER TOP. PRESS UP T/3000PSI & SET 7" LINER HANGER, SLACK OFF 100K & SET PACKER. TEST ANNULUS T/3500 PSI/HELD. RELEASE PACKER/POOH. DRILL OUT CMT MW: 0.0 VIS: 0 POOH & LD TIW PACKER SETTING TOOL. PU BHA, BIT, 4-3/4" DC'S, HWDP & MWD. RIH & TEST MWD. RIH SLM W/3.5" DP. RIH & PU 60 JOINTS OF 3.5" DP, XO T/5" DP, TAG LINER TOP @8184. RIH T/12527. NO CMT. PERFORM LEAK OFF TEST, EMW = 13.5 PPG. CIRCULATE & COND HOLE FLUID T/10.5 PPG. TAG @ 12528 CMT & RETAINER. RIH W/HOLE OPENER MW: 0.0 VIS: 0 DRILL OUT CMT RETAINER, FLOAT EQUIPMENT & SHOE. OBSERVE THE WELL. CBU & RECIPROCATE. WASH & REAM T/13228. PACKING OFF & HAD HIGH TORQUE. CIRC HOLE CLEAN. POOH & LD MWD. CHANGE BHA & PU HOLE OPENER. RIH T/6800. CUT DL. SERVICE THE RIG & RIH W/HOLE OPENER. CLEANING OUT 7" LINER MW: 0.0 VIS: 0 RIH W/6" HOLE OPENER, TAG UP @ 8400, WORK PIPE, CBU, ROTATE, WORK INTO LINER BUT STILL HANGING UP @8190. POOH & LD HOLE OPENER. PU DRILLING BHA W/6" BIT. TEST MWD. RIH T/TOP OF 7" LINER @ 8184. WASH & REAM T/11838 SEEING SIGHT BOBBLE ON WEIGHT INDICATOR. RECOVERED TEETH FROM THE 1ST 6" BIT. LD BIT, PU HOLE OPENER MW: 0.0 VIS: 0 WASH & REAM 7" LINER T/12638. WASH OPEN HOLE T/14655. PACKED OFF. POOH T/14320--TIGHT. CIRC WORK PIPE T/UNPLUG THE JETS. WASH F/14320 T/14660. CIRC HOLE CLEAN. SHORT TRIP T/7" SHOE @12638. TRIP IN HOLE, COULD NOT GET BELOW 13660. ROTATE IN AN ATTEMPT TO/GET BELOW 13660. UNSUCCESSFUL. POOH T/7" SHOE. CIRC T/FLUSH OUT 7" LINER. POOH. LD BIT & MWD, PU LC & HOLE OPENER. WELL : SDI 3-09 OPERATION: RIG : DOYON 15 PAGE: 9 04/05/95 (42) TD:14700' ( 0) 04/06/95 (43) TD:14660' ( 0) 04/07/95 (44) TD:14660' ( 0) 04/08/95 (45) TD:14660' ( 0) CIRC HOLE CLEAN T/TD MW: 0.0 VIS: 0 PU NEW BHA W/6" HOLE OPENER. RIH T/1900. CUT DL. RIH T/6595. SERVICE THE RIG & CHANGE SLIP DIES ON IRON ROUGHNECK. RIH T/SHOE OF 7" LINER. WASH & REAM T/14660. CIRC HOLE CLEAN. RUNNING 5" LINER MW: 0.0 VIS: 0 CIRC HOLE CLEAN. ROTATE & RECIPROCATE PIPE. SHORT TRIP T/12580 & BACK T/BTTM. HOLE IN GOOD CONDITION. PUMP LOW & HIGH VIS SWEEPS. CIRC HOLE CLEAN. TOOH T/RUN 5" LINER. SERVICE THE RIG. CHANGE OVER T/3.5" HANDLING TOOLS. TOOH W/3.5" DP & BHA. RU & RUN 5" LINER. RD CASG TOOLS & CLEAR FLOOR. CIRC LINER CAPACITY & ROTATE LINER. TORQUE WAS 110 AMPS OR APPROXIMATELY 1100 FT/LBS @ 15, 30 & 60 RPM. RIH W/LINER ON 3.5" DP T/6550. CHANGE HANDLING TOOLS T/5" RIH W/LINER ON 5" DP. MU BHA #15 MW: 0.0 VIS: 0 RIH W/LINER ON 5" DP. MU & SET BACK ROTATING HEAD. CIRCULATE LINER VOLUME. RIH W/LINER. TIGHT HOLE @13740. CIRC & ROTATE 5" LINER @30-70 RPM & 3.75 BPM. UNABLE T/GET PAST 13740. TOOH W/5" LINER. CHANGE HANDLING EQUIP. T/3.5" PU CASG EQUIPMENT. TOOH W/5" LINER. RU & LD 5" LINER. RU & TEST BOPE. WITNESS WAIVED BY DOUG AMOS W/AOGCC. MU 6" HOLE OPENER & BHA. LINER & HANGER LOOK GOOD. HANGER WAS SHIPPED T/BAKER F/CLOSER INSPECTION. FLOAT SHOE IS WORN FLAT ON THE BOTTOM. REAMING MW: 0.0 VIS: 0 TIH W/6" HOLE OPENER. SERVICE THE TOP DRIVE & CASING TOOLS. TIH W/6" HOLE OPENER. SLIP & CUT DRILLING LINE. TRIP IN HOLE T/SHOE @12638. CHANGED T/5" DP @ 6600. WASH & REAM HOLE F/12630 T/14429. THE ONLY TWO NOTABLE TIGHT SPOTS SO FAR WERE @13470 & 13740. NO PACKING OFF--SOLID & TIME CONSUMING ON THE CLEAN-UP. WELL : SDI 3-09 OPERATION: RIG : DOYON 15 PAGE: 10 04/09/95 (46) TD:14660' ( 0) 04/10/95 (47) TD:14660' ( 0) 04/11/95 (48) TD:14660' ( 0) 04/12/95 (49) TD:14660' ( 0) CIRCULATE MW: 0.0 VIS: 0 WASH & REAM HOLE F/14429 T/14660. TIGHT SPOTS @14359 & 14495. CIRC SWEEPS WHILE ROTATING & RECIPROCATING, SOME FINE GROUND CUTTINGS OBSERVED W/SWEEPS. TOOH T/7" SHOE @12638. OK. TIH T/14460. REAM TIGHT HOLE @13734 & 13917. CIRC SWEEPS. NO EXCESSIVE AMOUNT OF CUTTINGS OBSERVED. TOOH T/7" SHOE. OK. TIH T/14460. REAM TIGHT HOLE @12900, 13660 & 13735. CIRC SWEEPS. NO EXCESSIVE AMOUNT OF CUTTINGS NOTED. TOOH T/7" SHOE. OK. TIH T/14460, WENT THROUGH THE TIGHT SPOT @13725 WITHOUT PUMPING FOR THE FIRST TIME. CIRC SWEEPS & SPOT A HIGH VIS PILL IN THE OPEN HOLE. CIRC LINER @1466 MW: 0.0 VIS: 0 SPOT HIGH VIS PILL IN OPEN HOLE. TOOH T/RUN 5" LINER. CHANGE HANDLING TOOLS T/3.5" RU T/RUN 5" LINER, CUT & SLIP DL. RUN LINER. HELD PRE-JOB SAFETY MEETING. MU LINER HANGER. RU F/3-1/5" DP. RIH W/5" LINER T/12588. CIRC LINER & DRILL PIPE VOL. RIH W/5" LINER T/14661. ROTATED THROUGH TIGHT HOLE @12938 W/8500# TORQUE. NO OTHER PROBLEMS NOTED. RU BAKER ROTATING HEAD & CIRC .3BPM @ll00PSI. TRIP OUT OF HOLE MW: 0.0 VIS: 0 CIRC & ATTEMPT T/FREE THE STUCK LINER. CONDITION MUD F/107 PPG T/10.3 PPG & 24 YP. UNABLE T/FREE PIPE. TEST THE CMT LINES T/5000PSI. PUMPED 20 BBLS OF WATER, 70 BBLS SPACER & 195 BBLS OF CEMENT. DISPLACED W/206.9 BBLS OF MUD. BUMPED PLUG & SET LINER HANGER & RELEASED F/LINER W/4000. SET BACK ROTATING'CMT HEAD & PULLED 10 STANDS OF DP. CIRC BOTTOMS UP. NO CMT RETURN W/BTTMS UP. TOOH & LD LINER RUNNING TOOL & CMT HEAD. MU 6" ECONO MILL & BHA. TIH T/12193. WASH F/12193 T/12460. (TOL). FOUND NO CMT @ LINER TOP. CIRC BTTMS UP. NO EVIDENCE OF CMT OR CONTAMINATED MUD. TOOH. WELL SHUT-IN MW: 0.0 VIS: 0 TOOH W/6" MILL. CLEAR RIG FLOOR & RU 2-7/8" HANDLING EQUIP. PU 20 JTS OF 3-1/8" DRILL COLLARS, 54 JTS OF 2-7/8" DP, 4-3/4" COLLARS, JARS & 3.5" HWDP. CUT & SLIP DL. TIH T/THE TOP OF THE 5" LANDING COLLAR @14553. NO CMT. CBU. ATTEMPT CASING TEST. BROKE DOWN & PUMPED IN @1700PSI. OPEN UP & OBSERVE THE WELL BLED BACK 5 BBLS. TOOH T/RUN BOND LOG. HOLE FILL OFF BY 2 BBLS @7900. OBSERVE THE WELL. FLOWING. SHUT WELL IN & RECORD THE PRESSURE, AT 5:30 AM THE CASING HAD 50 PSI & @0600 IT HAD 100PSI. WELL : SDI 3-09 OPERATION: RIG : DOYON 15 PAGE: 11 04/13/95 (50) TD:14553' ( 0) 04/14/95 (51) TD:14770 PB:14553 04/15/95 (52) TD:14770 PB:14553 04/16/95 (53) TD:14770 PB:14553 RUNNING BOND LOG MW: 0.0 VIS: 0 WELL CLOSED IN W/100PSI ON CASG. 25 PSI ON DP. NO INCREASE SINCE 0600 HRS. AT 0700 HRS BLED WELL DOWN 1 BBLS T/0 PSI ON CASG. SHUT WELL IN F/1 HR. & PRESS BUILT T/55PSI @0800 HRS. BLED OFF 1 BBL T/0 CASG. PRESS & SHUT WELL IN UNTIL 0900 HRS. CASING PRESS @ 25 PSI. BLED PRESS & OPEN WELL. OBSERVE WELL UNTIL DEAD. TIH T/14553 @ LANDING COLLAR. CIRC BOTTOMS UP. MUD WT IS 10.3#. NO GAS ON BU. OBSERVE WELL. STABLE. TOOH T/8184. WELL IS FLOWING. OBSERVE THE WELL/ STOPPED FLOWING & STABLE. TOOH T/7230. OBSERVE THE WELL. NO FLOW & NO LOSS. WELL IS STABLE. TOOH T/RUN THE BOND LOG. ND FLOW NIPPLE & FLOW LINE. NU SHOOTING FLANGE. RU ATLAS LUBRICATOR & E-LINE. RIH W/ATLAS BOND LOG. RIH W/LINER TOP PACKER MW: 0.0 RUN BOND LOG. RD ATLAS WL & SHOOTING FLANGE. RU FLOW LINE. MU TIE BACK POLISH MILL & TIH. SLIP & CUT DL. TIH. SERVICE THE RIG. TIH T/5" LINER TOP @12460. POLISH TIE BACK SLEEVE @ TOP OF THE 5" LINER. CBU. MONITOR THE WELL. TOOH & LD MILL. MU 5" LINER TOP PACKER & TIH. LD 5" TEST PACKER MW: 0.0 TIH W/5" LINER TOP PACKER. SET PACKER IN TIE BACK SLOEEVE @12460. PUMPED DOWN DP F/3500 PSI CASING TEST. FAILED @1500PSI. PUMPED 10.7 BBLS TOTAL. SHUT PUMP DOWN & PRESS FELL' T/1200PS & HELD. BLED PRESS OFF & RECOVERED 10.7 BBLS. REPEATED PROCEEDURE W/SAME RESULTS. TOOH. TIH W/7" BAKER RETRIEVAMATIC PACKER & DUMMY TEST SEALS. CUT DL. TIH STING INTO LINER TOP PACKER W/DUMMY TEST SEALS. ATTEMPT T/TEST 5" CASG THROUGH LINER TOP PACKER. CIRCULATED AROUND LINER TOP PACKER W/3 BPM @700PSI. INDICATIVE THAT PACKER HAD NOT SET. SET TEST PACKER & TEST 7" X 9-5/8" CASG T/SURFACE @3500 PSI. CBU. TOOH W/TEST PACKER. LINER TOP PACKER CAME OUT OF THE HOLE W/DUMMY TEST SEALS. TRIP IN HOLE MW: 0.0 LD BAKER TEST PACKER, DUMMY TEST SEALS & LINER TOP PACKER. TIH W/BAKER POLISH MILL T/TOP OF 5" LINER @12460. POLISH THE TOP OF THE 5" SLEEVE @LINER TOP W/MILL. OBSERVE THE WELL, PUMP DRY JOB & TOOH T/12460. STING INTO TIEBACK SLEEVE W/PUMP ON UNTIL THE PRESS INCREASED. SHUT PUMP OFF & LAND. SET PACKER W/45000#. PRESS TEST ANNULUS T/3500 PSI. RELEASED F/PACKER & TEST CASG T/3500PSI F/30 MIN. TOOH & LD BAKER RUNNING TOOLS. CONDUCT WEEKLY BOPE TEST. WITNESS WAIVED BY JOHN SPAULDING AOGCC. TIH T/DISPLACE HOLE T/9.6 BRINE. WELL : SDI 3-09 OPERATION: RIG : DOYON 15 PAGE: 12 04/17/95 (54) TD:14770 PB:14553 04/18/95 (55) TD:14770' ( 217) 04/19/95 (56) TD:14770 PB:14553 DISPLACE W/9.6 PPG BRINE MW: 0.0 TIH W/4-1/8" MILL T/LANDING COLLAR F/BRINE DISPLACEMENT. WHILE BREAKING CIRCULATION, THE DP PLUGGED OFF. ATTEMPS T/CLEAR WERE UNSUCCESSFUL. TOOH WET. PIPE CAME DRY @ LAST 2 STANDS OF COLLARS. LD MILL & BIT SUB. NO OBSTRUCTIONS FOUND. CLEAN DRILL MUD OFF THE RIG FLOOR & SERVICE THE RIG. TIH T/5" LANDING COLLAR OE. BREAKING CIRC @ EVERY DP SIZE CHANGE. BREAK CIRC. PUMP 65 BBLS SEAWATER W/SAFE CLEAN, 100 BBLS SPACER & 250 BBLS SEAWATER @ 5 BPM WHILE ROTATING & RECIPROCATING. 9.6 PPG BRINE T/FOLLOW. PERFORATE 5" CASG MW: 0.0 VIS: 0 DISPLACE WELL W/9.6PPG BRINE W/2% KCL. TOOH. RU SHOOTING FLANGE, LUBRICATOR & ATLAS E-LINE. RIH W/PERF GUN & TIE IN W/CBT/GR. PERFORATE 5" CASING 4' SPF LOW SIDE/ORIENTED F/14488 T/14492. POOH. GUN FAILED T/FIRE. RIH W/5" EZSV CMT RETAINER & SET @14442. HAD CASING COLLAR-@ 14444. RIH W/PERF GUN & TIE IN W/CBT/GR. PERFORATE 5" CASING 4 SPF ON THE LOW SIDE. ORIENT F/14360 T/14364. POOH. SQUEEZE MW: 0.0 POOH W/PERF GUNS. RD ATLAS & SHOOTING FLNG. MU STINGER & 915' OF 2-7/8" TBG. TIH T/14440. STING INTO RETAINER. EST. CIRC. THRU PERFS @1/2 BPM W/1000 PSI. REV CIRC THRU PERFS @ 1/2 BPM W/750 PSI. CIRC BACK DOWN DP. THRU PERFS @1/2 BPM W/1000PSI. UNSTING F/RETAINER & CIRC SWEEP AROUND WHILE RU T/PUMP ACID. HELD SFTY MTG. PUMP 5 BBLS NH4CL. TEST LINES T/3500 PSI. PUMPED 5 BBLS OF NH4CL, 500 GAL OF 15% HCL, 1000 GAL OF 12% HCL + 3% HF & 20 BBL OF NH4CL. DISPLACED W/l14 BBLS OF 9.6 PPG BRINE. STUNG INTO THE RETAINER & PUMPED 20 BBLS OF NH4CL & ACID THRU PERFS. EST. CIRC RATE THRU PERFS @ 3 BPM W/900 PSI. FLUID LOSS @ 30 BPH. PULL OUT OF RETAINER & CIRC ACID OUT OF HOLE. BATCH MIX 15 BBLS OF PREMIUM CMT W/.2% OF CFR-3 & .45% HALAD 344 PLUS HR-5 F/RETARDING. PUMP 20 BBLS H20 + 15 BBLS CMT + 10.5 BBS H20. DISPLACE W/134.2 BBLS OF 9.6 PPG BRINE @ 5 BPM W/1350 PSI HOLDING 500 PSI BACK PRESS W/CHOKE. STING INTO THE RETAINER & PUMP 10.5 BBL OF H20 & 8 BBLS CMT THRU PERFS @ 3 BPM W/750 PSI. STOPPED PUMPING & PRESS FELL T/100PSI. UNSTING F/RETAINER & DUMP 7 BBLS OF CMT ON TOP OF RETAINER. LD 1 SINGLE & PULL 15 STNDS OF DP. PIPE WAS DRY WHEN THE SINGLE BROKE OFF. REV CIRC DP @ 3BPM & 575PSI. NO FLUID LOSS & NO CMT ON RETURNS. CLOSE WELL IN & HOLD 500PSI. WELL : SDI 3-09 OPERATION: RIG : DOYON 15 PAGE: 13 04/20/95 (57) TD:14770 PB:14553 04/21/95 (58) TD:14770 PB:14553 04/22/95 (59) TD:14770 PB:14553 04/23/95 (60) TD:14770 PB:14553 CIRC 'HOLE CLEAN MW: 0.0 HOLD 500 PSI ON DP W/HYDRILL CLOSED. OBSERVE THE WELL. POOH & LD 2-7/8" TBG & CMT STINGER. PU MILL, RIH W/2-7/8" & 3.5" DP & 4-3/4" DC'S. CBU. RIH W/3.5" & 5" DP. SERVICE THE RIG. RIH T/12460. CBU. RIH TAG CMT @ 13635. DRILL OUT HARD CMT T/14350. PUMP HI-VIS SWEEPS EVERY 225. CIRC HOLE CLEAN. RIH W/SCRAPERS MW: 0.0 CIRC HOLE CLEAN W/HI VIS SWEEP. TEST SQZ PERF'S W/1000PSI. POOH T/3.5" DP. CIRC @5 BPM/3000 PSI POOH & LD MILL. RU SHOOTING FLANGE & ATLAS WL LUBRICATOR. RIH W/PERF GUNS, SHOT 4 SPF @ 14308 T/14312. RIH W/4.1" GUAGE RING, TAG THE TOP OF THE 7" LINER @ 8184. UNABLE T/WORK RING DOWN, POOH--GUARGE RING HAD 4 MARKS ON IT AS IF IT HAD BEEN HITTING JUNK. RD ATLAS. ND SHOOTING FLANGE, NU FLOW LINE. CUT DL. PU 5" & 7" CASG SCRAPERS. RIH W/SCRAPER & 2235' OF 2-7/8" PAC. BREAK CIRC, CLEAR PIPE. R!H W/3.5" & 5" DP. DIDN'T SEE ANYTHING WHEN THE 5" SCRAPER ENTERED LINERS. PERFORATING THE 5" LINER MW: 0.0 CIRC HOLE CLEAN W/HI VIS SWEEPS. OBSERVE THE WELL. REPAIR INTERNAL BRAKE COOLING LINE. INSPECT DRILL LINE, CHANGE OUT DRILL LINE. POOH T/6000. FLOW ON DP DUE T/UNDERBALANCE. CBU. POOH & LD SCAPERS. RU SHOOTING FLANGE, RU ATLAS WL, RIH & SET CMT RETAINER ON WL @14268, POOH & RIH W/PERF GUNS T/PERFORATE 4 SPF 214210 T/14214. TEST BOPE MW: 0.0 POOH W/WL, RD ATLAS, RD LUBRICATOR & SHOOTING FLANGE, RU FLOW LINE. PU HALLIBURTON STINGER, RIH W/2-7/8" TBG. CIRC. CHECK RATE & PRESSURE. RIH W/3.5" DP. CIRC, CHECK RATE & PRESSURE. RIH W/5" DP. CIRC & CHECK RATE & PRESS. STING INTO' CMT RETAINER, ATTEMPT T/ESTABLISH CIRC THRU PERFS, JUG TIGHT @1300 PSI. REVERSE CIRC & ATTEMPT T/CIRC DOWN THRU PERFS. JUG TIGHT @1300PSI. OBSERVE THE'WELL, PUMP DRY JOB. POOH & LD HALLIBURTON STINGER. RU SHOOTING FLANGE & LUBRICATOR, RU ATLAS, RIH W/PERFORATING GUNS, SHOOT 4 SPF @ 14254 T/14258. POOH & RD ATLAS & SHOOOTING FLANGE, RU FLOW LINE. TEST BOPE. WELL : SDI 3-09 OPERATION: RIG : DOYON 15 PAGE: 14 04/24/95 (61) TD:14770 PB:14553 04/25/95 (62) TD:14770 PB:14553 04/26/95 (63) TD:14770 PB:14553 04/27/95 (64) TD:14770 PB:14553 04/28/95 (65) TD:14770 PB:14553 DRILL OUT CMT RETAINER MW: 0.0 INSTALL WEAR RING. PU HALLIBURTON CMT STINGER & RIH W/2-7/8" TBG & DP T/6392. CUT DL. RIH T/14280' BREAK CIRC, STING INTO CMT RETAINER & ATTEMPT T/ESTABLISH CIRC THRU PERFS-, JUG TIGHT @2000PSI, UNABLE T/CIRC. OBSERVE THE WELL, PUMP DRY JOB. POOH & LD STINGER. PU 4-1/8" MILL, RIH T/7300. SERVICE THE RIG, BREAK CIRC. RIH T/CMT RETAINER @ 14280. MILLING OUT CMT RETAINER @14280. CLEAN OUT CMT RETAINERS MW: 0.0 MILL OUT CMT RET @14280 & PUSH T/14350. MILL ON RET. JUNK. OBSERVE THE WELL. POOH F/MILL, LD. MILL IS WORN & HAD A CHUNK OF RETAINER JUNK STUCK T/BTTM. RIH W/NEW MILL T/7300. CUT DL. RIH T/14350. MILL OUT RETAINER JUNK @14350 & CLEAN OUT CMT T/TOP OF RETAINER #2 @14455'. MILL OUT CMT RETRIEVER MW: 0.0 MILL OUT CMT RETAINER @14451. TEST PERF T/1000PSI, GRADUALLY INCREASE T/.1900 PSI. PRESS BLED OFF 400PSI/30 MIN. MILL ON CMT RETAINER. OBSERVE THE WELL. POOH F/MILL. RIH T/8000. CBU. RIH T/RETAINER @14451. MILL OUT CMT RETAINER. ADD 8.5" NON-ROTATING STAB T/5" DP @ SURFACE. POOH LD DP MW: 0.0 MILL OUT RETAINER & CMT T/14492. TEST PERFS T/1000PSI/15 MIN. & INCREASE T/1400PSI/15 MIN. OK. MILL OUT CMT T/14536, TAG LANDING COLLAR @14541. CLEAN PITS, TAKE ON 8.5 PPG SEAWATER, WT UP T/9.1 PPG. CHANGE WELL OVER T/9.1 PPG BRINE. POOH LD DP. RIH W/COMP STRING MW: 0.0 WORK ON PIPE SKATE, ELECTRONIC CONTROL. POOH LD DP, RAN PIPE OUT OF DERRICK, POOH & LD. PULL WEAR RING. RU T/RUN 4.5" TBG & BAKER 7" SAB 3 PACKER. RIH W/4-1/2" PU BALL VALVE, TEST CONTROL LINES T/5000PSI. WELL : SDI 3-09 OPERATION: RIG : DOYON 15 PAGE: 15 04/29/95 (66) TD:14770 PB:14553 RIG RELEASED MW: 0.0 RIH W/7" BAKER PACKER ON 303 JTS OF 4-1/2" CR-13 TBG & 5 GLM'S, 1 SSSV. REV CIRC 524 BBLS OF 9.1 BRINE TREATED W/CORROSION INHIBITOR @ 3 BPM. DROP PKR SETTING BALL, MU CL T/HNGR, TEST T/5000PSI, LAND HNGR IN TBG SPOOL. PRESS UP ON TBG, SET BAKER PKR W/4000PSI, HELD PRESS 30 MIN. HELD 1500PSI ON TBG. TEST ANNULUS T/3500PSI/30 MIN. SET 2-WAY CHECK VALVE. ND BOPE, CLEAN PITS. NU ADAPTER FLANGE & TREE, TEST CONTROL LINE, TREE & FLANGE T/5000PSI. PULL 2-WAY CHECK W/DSM LUBRICATOR. FREEZE PROTECT TBG & ANNULS T/1500 W/DIESEL. INSTALL BACK PRESS VALVE IN TBG HNGR. SUCK BRINE OUT OF PITS & SLOP TANK & INJECT 830 BBLS DOWN WELL 4-10. RD ESD SYSTEM. RELEASE RIG @02:30 HRS. SIGNATURE: (drilling superintendent) DATE: SeERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 SHARED SERVICES DRILLING ENDICOTT / 3-09/L-28A 500292178001 NORTH SLOPE BOROUGH COMPUTATION DATE: 4 / 1 / 95 TRUE SUB-SEA COURS COURSE MEASD VERTICAL VERTICAL INCLN DIRECTION DEPTH DEPTH DEPTH DG MN DEGREES DATE OF SURVEY: 032395 ELECTRONIC MULTI-SHOT SURVEY JOB NI31~BER: AK-EI-50019 KELLY BUSHING ELEV. = 79.40 FT. OPERATOR:f~BP%BX, RL.ORATION DLS TOT, ~£~L RECTANGULAR COORDINATES VERT. DG/100 NORTH/SOUTH EAST/WEST SECT. 13828 9791.07 9711.67 59 19 N 59.96 E .00 13842 9798.42 9719.02 59 9 N 59.55 E 2.72 13938 9847.68 9768.28 58 45 N 59.96 E .57 14033 9897.80 9818.40 58 0 N 59.34 E .95 14130 9949.18 9869.78 57 30 N 59.55 E .56 6444.91N 412.08E 3855.75 6451.13N 422.75E 3868.08 6492.35N 493.45E 3949.83 6533.49N 563.70E 4031.15 6574.89N 633.84E 4112.52 14226 10001.53 9922.13 56 49 N 59.19 E .76 14322 10054.96 9975.56 55 44 N 59.56 E 1.18 14417 10109.84 10030.44 53 38 N 59.93 E 2.23 14512 10166.61 10087.21 52 19 N 60.03 E 1.39 14607 10226.56 10147.16 49 40 N 59.95 E 2.79 6616.22N 703.64E 4193.57 6657.01N 772.53E 4273.57 6696.05N 839.46E 4350.96 6733.72N 904.66E 4426.16 6770.75N 968.76E 4500.09 14632 10242.84 10163.44 49 2 N 59.84 E 2.54 14700 10287.15 10207.75 49 2 N 59.84 E .00 6780.26N 985.17E 4519.03 6805.91N 1029.31E 4570.02 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 6883.30 FEET AT NORTH 8 DEG. 36 MIN. EAST AT MD = 14700 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 57.00 DEG. TIE IN POINT 13,828.26' INTERPOLATED DEPTH 14,700' sPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 SHARED SERVICES DRILLING ENDICOTT / 3-09/L-28A 500292178001 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/ 1/95 DATE OF SURVEY: 032395 JOB NUMBER: AK-EI-50019 KELLY BUSHING ELEV. = 79.40 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 13828 9791.07 9711.67 14700 10287.15 10207.75 6444.91 N 412.08 E 4037.19 6805.91 N 1029.31 E 4412.85 375.66 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SI/N DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 SHARED SERVICES DRILLING ENDICOTT / 3-09/L-28A 5oo292178oo1 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/ 1/95 DATE OF SURVEY: 032395 JOB NUMBER: AK-EI-50019 KELLY BUSHING ELEV. = 79.40 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE MEASD VERTICAL DEPTH DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 13828 9791.07 13999 9879.40 14186 9979.40 14366 10079.40 9711.67 6444.91 N 412.08 E 4037.19 9800.00 6518.46 N 538.36 E 4119.62 9900.00 6598.87 N 674.54 E 4206.74 10000.00 6675.19 N 803.48 E 4286.89 82.43 87.12 80.15 14532 10179.40 14688 10279.40 14700 10287.15 10100.00 6741.90 N 918.84 E 4353.51 10200.00 6801.42 N 1021.59 E 4408.77 10207.75 6805.91 N 1029.31 E 4412.85 66.62 55.26 4.08 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS ~ 1.01 5,::., ": ::, _. '" o,,_, ....., ~' i5,--",74 230:44 -.~-,- .~ DJ'J/ i :. o-:-~. ~ .z.: ?-: :3 86.2::: 79 1 l&;:Y:b,,' ,~G:3 ~ 1732,72 3372 ...... :.c,, 67 54,31 564)3 53.--91 ,._,., .3.'1: _. ::,-2275.77 94,? ~'"" 12375,'*= ........ o.: Y'f,.4 -,?:,-' L,,:o %-',..? ?OW2:?9 :,, ..... ,, ,-.. ?113,16 :, ,--,,r:.~:, ~ 97,3 r-~ h ~' ~.4 I-,a-: .~ ~}. I%. I ~o~.,.~ u.~ 9 4..- t r ~,' ,--, 2,: 13048.80 95,4 93~,20 l_.'ic:,7? 56, % 56,31 i.z.~5,78 ~,99 55,10 i?&A o=. 57.16 tM6,24 ~,82 -so::O~; 5?5,4,_. o_,.:- :.,% .. _, _ . .J.JC" ,, 2"t L ,,. 7'~' -2?5.,.., c, 6032.03 3~.17 0.28 "' ';'"' -227,62 ~A)7i,61 ~" ~'~' .,.~r,o_, 1,23 -159,65 MiI,6i ~.8,.5() (;,53 ., -:7; ?2:7 o-'--?. ~--', · 5 ~5S4:34 %:3 " LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 9 May 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL 3-09/L-28A DESCRIPTION 1 SBT/GR FINAL BL+RF 1 GR/CCL FINAL BL+RF ECC No. Run ~ 1 6397.08 Run # 1 6397.09 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services . _ 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: Please s i~ and '~etu~'~ Petro'bechnical Data Cente~ BP Exploration (Alaska) 900/~st Benson Boulevard .... ,~-~ ..-~ ~. Al~ska Oil & Gas (;ohs. Commission Anchorage LARRY GRANT Attn. A~ASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 25 April 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL 5-/? DESCRIPTION PLS FINAL BL+RF PFC/PERF FINAL BL+RF GR/CCL FINAL BL+RF PFC/PERF FNL BL+RF PFC/PERF FINAL BL+RF PLS/STP FINAL BL+RF ECC No. Run # 1 5937.08 Run ~ 1 6397.05 Run # 1 6397.06 Run # 1 Run # 1 6397.07 Run #" 1 6412.00 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date .' Please sigu and return P~t - ---rozeehnical Data Centex- -BP E:~ploration (Alaska) Ino 900 East Benson Boulevard LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 25 April 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~'~- I) ~ ~-~v-~o ~ 5- !? ~-o~-~ ~- 19 ~-o~-~ DESCRIPTION PLS FINAL BL+RF PFC/PERF FINAL BL+RF GR/CCL FINAL BL+RF PFC/PERF FNL BL+RF PFC/PERF FINAL BL+RF PLS/STP FINAL BL+RF ECC No. Run # 1 5937.08 Run # 1 6397.05 Run # 1 6397.06 Run # 1 Run # 1 6397.07 Run # 1 6412.00 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: Please s~gn and ~1,e%u~n %0; ~ .. ~o uechnteal Da%a Gen%e~ SP E:{ploratfon (Alaska) Ino 900 Ea;~t Benson Boulevard ECEI'VED o s~lon LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 25 April 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~'~_/)~ ~-~v-~0 ~/5-/? ~-o~/~-~ ~5'- 19 ~-o,/~-~ gE- {9 DESCRIPTION PLS FINAL BL+RF PFC/PERF FINAL BL+RF GR/CCL FINAL BL+RF PFC/PERF FNL BL+RF PFC/PERF FINAL BL+RF PLS/STP FINAL BL+RF ECC No. Run # 1 5937.08 Run # 1 6397.05 Run # 1 Run # 1 6397.06 Run # 1 6397.07 Run # 1 6412.00 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: Please slgu and me%u~n %~; Petz'otechntcal Da~a Cente~ SP E:zploration (Alaska) In~ 900 East Benson Boulevard ECEI.VED LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 24 April 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION 1 GR/CCL FINAL BL+RF 1 PFC/PERF FINAL BL+RF ECC No. Run # 1 4054.01 Run # 1 6397.04 Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: \~ ~~~~ Date: ~..~.. ,~.. tec~"4'i lcal Data Genre= {?,.r.~ Ex.~.].o-r~tion (Alaska) 900 East Benson Boulevard ~chorage, ~aska 99508 LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Reference: BP · 3-09/L-28A ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: DIFL/GR FINAL BLSRF ZDL/CN/GR FNL BL+RF BH/PRO FINAL BL+RF SSVD FINAL BL+RF Date: RE: 21 April 1995 Transmittal of Data ECC #: 6397.00 Sent by: PRIORITY MAIL Data: OH-LDWG Run # 1 Run # 1 Run # 1 Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201. Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: ~, ~~ Date: R ¢,EIV D APR 2_ 7 1995 Alaska 0~1 & Gas Cons. Comnd~ion Anohorage Please si~n and return ~ ica% Data cente~ ?etroteChn.~.__ /Alaska) Received-''"~'~ __ LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 19 April 1995 RE: Transmittal of Data ECC #: 6'397.02 Sent by: PRIORITY MAIL Data: SBT/GR Dear Sir/Madam, Reference: BP 3-09/L-28A ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 SBT/GR FINAL BL+RF Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or ~ ~o ~0~,.~ ~-~0~ RECEIVED Alaska Oil a Anchorage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 18 April 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION 3-09/L-28A 1 LDWG TAPE + LIS ECC No. Run # 1 6397.02 Run # 1 6397.00 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: Please s i~n and return ~ Petrotechniual Data Cente~ BP Exploration (Alaska) Ine 900 East Benson Boulevara '-- ' Received bb' ; APR 2 7.1 i;~t,e Alaska'Otr& ~'as Cons. Commission Anchorage MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David John_~n~ DATE: Chairmad~ March 13, 1995 THRU: Blair Wondzell, ~/~-~~ FILE NO: P. !. Supervisor Bobby Foste ~ ECT: FROM: ~ SUBJ Petroleum Inspector ALHICNCD.doc BOPE Test- Doyon 15 BPX - DIU - SDI - 3-09/L-28A PTD # 95-0019 Endicott Field Monday, March 13, 1995: I received a call from James Carlile, BPX drilling rep., informing me that he was going to pull dut of the hole for a bit change and wanted to test the BOPE while out of the hole even though the test would be 1 day early. I agreed to this and went to the rig at 5:00PM. The rig had a few delays getting out of the hole and the test began at - Tuesday, March 14, 199.5:12:05 AM and was completed at 4:00AM. As the attached AOGCC BOPE Test Report shows there were no failures. All the gas detectors were in operating order and calibrated. The location and rig was clean and orderly. All other equipment seemed to be in good working order. Summary: I witnessed the BOPE test on Doyon rig 15 - test time 4 hours - no failures. Attachment: ALHICNCD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drig Contractor: DOYON Operator: BPX Well Name: SD1-3-Og/l..-28A Casing Size: 9.625' Set @ Test: Initial Weekly Rig No. 15 PTD # Rep.: Rig Rep.: 10,522 Location: Sec. X Other 95-0019 DATE: 3/14/95 Rig Ph.# 659-6510 JAMES CARLILE MIKE DRODDY 8 T. 11N R. 17E Meridian U MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location oK Standing Order Posted OK Well Sign OK Drl. Rig OK Hazard Sec. OK FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F 1 500/5,000 P 1 500/5,000 P I 500/5,000 P I 500/5,000 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F I 300/3,000 P 1 500/5,000 P I 500/5,000 P I 500/5,000 P 1 500/5,000 P 2 500/5,000 P I 500/5,000 P N/A MUD SYSTEM: Visual Alarm Trip Tank YES YES Pit Level Indicators YES 'YES Flow Indicator YES YES Meth Gas Detector YES 'YES H2S Gas Detector YES YES CHOKE MANIFOLD: No. Valves 18 No. Flanges Manual Chokes Hydraulic Chokes I Test Pressure 500/5,000 46 500/5,000 2 P Functioned Functioned P/F P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 4 ~. 2500 3,050 I P 1,350 P 0 minutes 41 sec. minutes 41 sec. YES Remote: YES Psig. Number of Failures: 0 ,Test Time: 4.0 Hours. Number of valves tested 26 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 ~-=~or,o,~S~opc~'.gcr,o. 6~9-~7or~g7 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: GOOD TEST- NO TE: 24 HOUR NOTICE NOT GIVEN DUE TO HA VING TO PULL DULL BIT EARL ¥. Distribution: odg-Well File c - Oper./Rig c- Database c - Tdp Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES NO X Waived By: W'rtnessed By: BOBBY D. FOSTER F1-O21L (Rev. 12/94) ALHICNCD.XLS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 February 21, 1995 A C Clark, Drlg Engr Supv BP Exploration (Alaska) Inc P O Box 196612 Anchorage, AK 99519-6612 Re: Well # Company Permit # Surf Loc Btmhole Loc Duck Island Unit/Endicott 3-09/L-28A BP Exploration (Alaska) Inc 95-19 2750'NSL, 838'WEL, Sec 8, T11N, R17E, UM 4278'NSL, 5104'WEL, Sec 4, T11N, R17E, UM Dear Mr Clark: Enclosed is the approved application for permit to re-drill the above referenced well. The permit to re-drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting re-drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling a new hole. Notice may be given by contacting the Commission's petroleum field inspector on the Nodh Slope pager at 659-3607. David W Joh ston BYORDER OF TH COMMIS ION jo/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] RedrilllDIlb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration BKB--56 feet Endicott Field/Endicott Pool 3. Address 6. Property Designation P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 47503 4. Location of well at surface 17. Unit or property Name 11. Type Bond(see 2o AAC 25.025) 2750' NSL, 838' WEL, SEC. 8, T11N, R 17E Duck Island Unit/Endicott S,~ / At top of productive interval 8. Well number Number 4090' NSL, 115' WEL, SEC. 5, T11N, R17E 3-09/L-28A 2S100302630-277 At total depth 9. Approximate spud date Amount 4278' NSL, 5104' WEL, SEC. 4, T11N, R17E 2/21/95 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD andTVD) property line ADL 47502-1002 feet No close approach feet 2560 11522' MD/8544' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.o35 (e)(2)) Kickoff depth 10540 feet Maximum hole angle 57 o Maximum surface 3900 psig At total depth (TVD) 10000'/4890 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD M D TVD (include stage data) 8-1/2" 7" 26# L-80 LT & C 1075' 10450' 7880' 11522' 8544' 218 sx Class "G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary FEB '1 7 1995 Total depth: measured 15800 feet Plugs (measured) Alaska 0il & Gas Cons. Commission true vertical 10091 feet Anch0ra,.~; Effective depth: measured 15800 feet Junk (measured) true vertical 10091 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 122' 30" Driven 161' 161' Surface 2473' 13-3/8" 3254 cu fl Permafrost 2512' 2512' Intermediate 14147' 9-5/8" 1150 cu fl Class "G" 14186' 9821' Production 1056' 7" 594 cu fl Class "G" ~3~6~,.~4923, 9678'-10002' Liner 909' 4-1/2" Uncemented Slotted ~4~,,.~7~8, ~'.~oo9~' Perforation depth: measured Slotted Liner @ 14889'-15798' true vertical (Subsea) Slotted liner @ 9944'-10036' 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program [] Drilling fluid program [] Time vs depth I~lot [] Refraction analysis l-'l Seabed reportl-] 20 AAC 25.050 requirements[] 21. I hereby certify that the foregoing )/s//,Jrue.,a~d corred to the best of my knowledge . Signed /'~/~, "~,1~--~~~"/~//~'/_~, / ' '~' ,~ff Title Driling Engineer Supervisor Date ~//~0/~'~'5 .... ~__~. ,..- - / \' -- - , ' 't Comm~'Tssion Use Only / / Permit Number APl number Approval date ISee cover letter ~,,~_/~ 150- ~2-~'-.~,/~8"4::~-o.~ ,~- ¢q/'. ~"- for other requirements Conditions of approval Samples required [] Yes ];~[NO Mud Icg required []Yes ~ No Hydrogen sulfide measures [] Yes ~ No Directional survey required ~ Yes [] No 1-12M; []3M; ~J~5M; •10M; [-115M' Required working pressure for BOPE Original Signed~y ' Other: by order of ~_/.~ /~ Approved by David W. Johnston Commissioner the commission Date / Form 10-401 Rev. 12-1-85 Submit in trip icate I Well Name: 3-09/L-28A Redrill Plan Summary Type of Redrill (pr~pduc.er_o[, injector): ] Producer iSurface. Location: T?_ get Location: [ Bottom Hole Location: 2750 FSL 838 FEL S08 TIIN R17E UM 4090 FSL 115 FEL S05 TI 1N R17E UM 4278 FSL 5104 FEL S04 T11N R17E UM [AFE Nmnber: ] 727001 ] IEstimated Start Date: [ 2-21-95 1 I MD: 111522 I [TVD: Well Design (conventional, slimhole, etc.): I Rig: I DOYON 15 IOperating days to complete: 24 8544 I II<BE: CONVENTIONAL SIDE TRACK 156 Objective: 2A/2B PRODUCER 9970TVD/9845TVD Top Tuffs 12,552'MD 9106' TVD Top HRZ 13,451 MD 9596' TVD Top Put River 13,928'MD 9856 TVD Top Kekiktuk 13,965' MD 9876TVD MILLING FLUID Program: A 10.00.ppg Biozan po~ymewater based FLUID will be used. [ Special designconsiderations !10PPG BIOZAN POLYMER WATERBASE Depth Density PV YP INT 10MIN FL OIL SOLIDS (TVD) (PPG) (CP) (#/FT) GEL GEL cc/30min (%) (%) KOP' 10.0 50 20 30 6 0- ,,, tO tO tO tO tO tO tO tO tO --2-rgb- ..... i0.0 ...... -80' 30 40 8 0 OD KOP Mud Program: A 9.5 - 10.00 p~pg Biozan polymer/KC1 water based mud will be used. Special design ~ 10PPG WATERBASE considerations 1 RECEIVED FEB 1 7 1995 Alaska Oil & Gas Cons. Commission Anchora.:e Re&ill Plan Summary Page 1 Depth DenSity ' -PV YP INT ' 10MIN FL OIL SOLIDS (TVD) (PPG) (CP) (#/FT) GEL GEL cc/30min (%) (%) KOP' 10.0 ~10 '" 15 5 10 ' 10 0 5 to to to to to to to to to 'T~'-~ i010 ~-. -"~8 .~ _..3_9 is .... 30 5 0 8.. Directional: I-K0p:' I ~0,540 Mr) IMaximum Hole Angle: [ 57 Close Approach Well: ! NONE The above listed wells will be secured during the close approach. Casing/Tubin: Program: Wi/Ft '~ Hole Size .... Csg/ Wt/Ft Grade Conn L/~ngth Top " Btm Tbg O.D. MD/TVD MD/TVD '8.5 7 26 L-80 LT& 1075 10450/7880 11522/8544 C ,.. , Cement Calculations: iLiner Size: I Basis!i 50?0 open hole excess, 40'.. shoe joint, 150.'. liner lap and 150' excess abov~ line} with DP. Total Cement Volume: 218 sxs of Class G Blend @ 1.18 ft3/sx , ,, ~Liner Size: Basis:i_50% open ho'l~ e>~'~ess, 2~0' 'ih6~ joi'fit, 150' liner !..aP an.d 150' exCess above linei' with DP. Total Cement Volume: sxs of Class G Blend @ 1.18 ft3/sx RECEIVED Redfill Plan Summary FEB 1 7 ]995 abska Off & Gas Cons. Commissi~age 2 Anchor&/, Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics on file with AOGCC. Redrill Plan Summary RECEIVED .~}~ska Oil & Gas Cons. Cornmissi~'~ge 3 gnchor~. ::, 3-09/L-28A ST 2/15/95 SUMMARY__ PROCEDURE:3_-09/L-28A 1. Pre-rig work: Test intermediate casing emergency pack-off to 3000 psi. Test casing to 3500 psi. Bullhead SW down 4.5" tubing, record injection rate and pressure. Cut tubing at 10,750' Freeze protect and set a BPV. 2. Pull BPV. 3. After ensuring that the well is dead. Set BPV. Remove the production tree. 4. Install BOP's and test to 250/5000 psi. Monitor volumes carefully to ensure that the fluid is not being pumped down tubing. Remove the test plug and BPV. 5. Pull and lay down the 4.5" tubing. Install wear ring. . P/U cement retainer. RIH and set it ,,, 200' ( at 10,740' ) below proposed 9-5/8 section. P&A well by using down squeeze method. ( To be witnessed by AOGCC. This is as per sundry procedure) a. Establish injection rate prior to pumping cement NOTE: FISH in #3 GLM 4.5 plug can pump past 2BPM 3400 psi. b. Pump total of 30bbls of P & A cementand 52 BBI brine under retainer c. Unsting out of bridge plug and POOH. The objective_of this P & A is: a. Squeeze away 5 bbls of cement slurry ( 5 bbls ) b. Cover up perfs and up to 200' MD above the perfs ( 16.6 bbls ) c. Will pump 80% of excess ( 13.3 bbls ) d. Total of 30 bbls of slurry , , 10. 11. 12. '13. 14. 15. 16. 17. 18. 19. Displace to milling fluid and spot a 18 ppg pill on bottom. POOH and P/U 9-5/8 section mill cut a 50' section in the ,9-5/8" casing starting from about 8800' MD.. Spot a balanced cement kick-off plug (180 cubic feet minimum) through open- ended drillpipe from 100' below the base of the section to 200' above the top of the section. Run in with an 8-1/2" steerable drilling assembly ( GR/MWD ) and dress the cement to 5' below the section top. Prior to kickoff circulate hole clean so that it is free of cement. Kickoff and directionally drill to the target with 52° hole angle at _10,j75ss as per the attached directional plan. Obtain DIL/MSFL/LDT/CNL/GR/CAL FMT(15POINTS) formation evaluation logs stalling from the top of the 9820' Kekiktuk Fm. Run a Z" 29_#__Lz_80 liner assembly to bottom in the 8-1/2" hole and space the liner hanger (L-80) about 150' up inside the 9-5/8" casing. Cement the liner in place with the total cement volume based upon 50 % open- hole enlargement plus the 80' shoe volume, 150' lap volume and 150' excess on top of the liner with drillpipe in the hole. ( Note: if the caliper Icg is available use it and add 20% to caliper volume ) Run the 4-1/2" 13CR-80 completion string assembly. Space out and circulate with corrosion inhibitor before setting the tubing packer. Test tbg to 4000 psi. ( Refer to completion diagram and standard completion running procedure ) Install TWC. Test TWC to 1000 psi. Remove BOP's. After completing this well TREE ( 7-1/16"x 4") against TWC to 5000 psi. After testing is completed pull TWC and install BPV. Test the tubing x casing annulus to 3500 psi for 30 minutes. Shear RP valve in the upper GLM and freeze protect the well. Fill out all necessary forms and hand them over to production. Release the rig. Page 15 RECEIVED FEB 1 7 1995 hi~.,ska 0ii & 0as Cons. C0mraission gnchor~ .-.. 3-09/L-28A ST 2/15/95 Hazards and Contingency Plans: Prior to ND Tree Please Discuss Barrier Variance Letter with Drillincl -- S__upe~jnte___ndent and with Point Contact It is important to no_re the followin_g: a) Reservoir pressure variance of 1050 psi is expected 3400psi to 4450 psi @ 10,000 TVDss / ????? MD the pore pressure most likely will be @ 8.6 ppg Please watch and check for gas while drilling this interval. Check for flow as soon as this sand is drilled to ensure that the well is not flowing. NOTE :The original reservoir pressure was 4890 psi @10,000 this may be encountered at any point within the Kekiktuk due to hydraaulic discontinuities within the formation. b) Because of risk of differential sticking HPHT fluid loss should be controlled between 10-15ml/30 min (200 degrees/500psi.) c) d) e) f) g) Watch for Key seating and potential for STUCK PIPEin the Colville group. As out on the PAD DATA SHEET. Tuffs and HRZ are notorious tight hole intervals Gas expected 2 9900'TVDSS in upper 2B lower 2B should be oil. Water 10025' will be encountered in the lower 2A. Casing not cemented increase kick off cement volume per RP 9-5/8 sidetracks version 3.2. paragraph 18. Page 18 RECEIVED FEB 1 7 1995 Ai~ska 0il & Gas Cons. Commissior~ .Anchors.." FEB-14-1995 11:45 FROM ANRDRILL TO PBD ENGINEERS P.O? · , ; SHAREB""S' [::i91CES DR ILL I Ne.' .... i i i i · i iji i ___ i iii ii i1~11 , i i · 3-0 L-28A 6 ,,, TIE-T, ,0501. ,4684 1.43.5 ~: PLAN VIEN O) END OF' 6/100 CURVE 115~ 53915 lJ. SJ. CLOSUREi ' 6881. feet at Azimuth 8,32; El TAAGET-~SO' RADIUS 13203 6620 703 DECLINatION.' 29.B67 E FI TO ~4~6 6~og ~9~ SCALE ! ' t incl~ ~ 500 feet DRA~IN '~ ' 0~/~4/~5 I, ! _ ~nadri]] Sch]umDer'gen ' i ----78~n, . ..... · ........ , A ADRILI. j:. AK~,-DPC . , · I ~ ) I ' ' 7000 ' F~ o '~ 4 baa: , ~ , I ' , . INITI~ i 'F' 6750 ........... ~- ...................................... ~oo-- , i' I , ,, i ~ T~IqGEf 150 FT RADIUS ' ~o- - i ......................... / ............. ' ......... ! .. ! 13000 : · ~, ............... J ~ , t . ' .... ,' 5250 ............... , I ..... ' ..... .. -- ' 'i .......... % . .. · · , ,, ,,,5000-- i T · i. , , i , · ; \ · : .995 42~o ............. t "~'' : ~_ .. Alaska Oil.&' .. · , ' ...... ~s C. ot~;:~omm~sr ..... ~ ' loll m', ' aooo I , : I r i ...., , -- ~000 ~750 ~500 1~50 lO00 750. · 500 ~50 0 250 500 750 2000 1250 2500 i : · ;' <- I/EST · EAST -> i TOTRL P, 0? SHARED 'SERVTCES i iii ....DRILLING I Anadr i 11 Sch]u~berger i ii -3-09/L---28-A ......... ('P VERTICAL SECTION VIEW Section at: 57 O0 ~ ' . h = 500 feet i ~ I - ~ , IOep Scale.: ! inch = 500 feet , ,~'~ I% 7~-I~'r ~ " ~:' APPROVED '~- ~ : Harker ldentificatioa HD BKB SECTN INCL : [FEB ~. Al !!~-I~ 10501 79~.1 1347 57.a ;. ~ ~'~ C) K~ C~VE 6/100 10545 7956 t358 56.t ~-J .... ~---l, ......... INiTiAL .~ ~:, m t~ OF 6/,o0 cua~ ,,5~ 8544 ' ; '- --' E) laa~-t50' aaol~ 14~03 10006 4196 56.S _ . - - ~ ~ ...... : .: .. FI. lO ....... i46i6 t0~31..4542. .56"~. ' ~ ' . - ............... . .................... I ,, -' .. -~nm- ~,~- ......... ~( ................... '~ ~ ~ I ~ i x ~ ~'-' - ...... ~ .................. ......... 4 ........ g ............. ~ - - - _ ~~fi~=:'==: =::=== .... ~_=5~ ..... . ..... ~ .................... ~ ..... - .... 7---:=~---5L===: _. ~ : ............................................. ~ ................... ~ ................... h .................. I .................... : .... ~000 1250 t500 1750 2000 2250 2500 2750 3000 3250 3500 3750 4000 4250 4500 4750 5000 5250 5500 ............................................................................................ se'c-t'i'b'n-' De~ia-~ [ IAn~dr~l) [c)93 30~L21~6 Bt.5~ ti: 17 ~ 1) _] "rl rtl I I m Z Z m m WELL PERMIT CHECKLIST , dev [] redrll~ serv [] ON/OFF SHORE O~J ADMINISTRATION 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary.. 6. Well located proper distance from other wells ..... 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party ............. 10. Operator has appropriate bond in force ........ 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval. 13. Can permit be approved before 15-day wait ....... ENGINEERING N N N N N · N N N N .Y N 14. Conductor string provided ................ 15. Surface casing protects all known USDWs ......... 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndrmLnt been approved. 22. Adequate wellbore separation proposed ......... 23. If diverter required, is it adequate ........... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ..................... 26. BOPE press rating adequate; test 'to ~ psig.tY,' 27. Choke manifold complies w/API RP-53 (M~y 84) ...... 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ............. GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... 32. Seismic analysis 9f shallow gas zones .......... 33. Seabed condition survey (if off-shore) ....... './Y 34. Contact name/phone for weekly progress reports . . ./.. Y N [exploratory only] GEOL/O~: ENGINEERING: COMMISSIO~N: TAB '~'"'~'; ' Comments/Instructions: HOW/~o - A:~FORMS~,cheklist re~ 03/94 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : BP EXPLORATION (ALASKA) INC. WELL NAME : 3-09/L-28A FIELD NAME : ENDICOTT BOROUGH · NORTH SLOPE STATE : ALASKA API NUMBER : 500292178001 REFERENCE NO : 98082 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/02/12 ORIGIN : FLIC REEL NAME : 98082 CONTINUATION # : PREVIOUS REEL : COI~ENT : BP EXPLORATION, 3-09/L-28A, ENDICOTT, API# 50-029-21780-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/02/12 ORIGIN · FLIC TAPE NAME : 98082 CONTINUATION # : 1 PREVIOUS TAPE : CO~4~FT : BP EXPLORATION, 3-09/L-28A, ENDICOTT, API# 50-029-21780-01 TAPE HEADER ENDICOTT CASED HOLE WIRELINE LOGS WELL NAME: 3 - 09/L-28A API NUMBER: 500292178001 OPERATOR: BP EXPLORATION (ALASKA) INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 12-FEB-98 JOB NUMBER: 98082 LOGGING ENGINEER: CAIN OPERATOR WITNESS: BARBA/CLUMP SURFACE LOCATION SECTION: 8 TOWNSHIP: 1 IN RANGE: 17E FNL: 2530 FSL: FEL: 838 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 56. O0 DERRICK FLOOR: 56. O0 GROUND LEVEL: 14.50 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 7. 000 14850.0 12.60 2ND STRING 4. 500 12380.0 18. O0 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH 88888.0 14210.0 14207.0 14188.0 14186.5 14185.5 14167.0 14165.5 14164.5 14160.0 14159.5 14156.0 14154.0 14151.5 14147.5 14136.0 14117.5 14113.0 14095.5 14094.5 14093.0 14088.5 14087.0 14084.0 14082.0 14073.5 14071.0 14065.5 14062.5 14061.5 14057.5 14053 0 14050 0 14041 0 14039 5 14030 0 14029 0 14025 0 14024 5 14017 0 14014 0 14009 0 14008 5 14002 5 14002 0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH PDK 88889.0 88887.0 14187.5 14169.0 14166.0 14161.5 14159.0 14153.0 14148.0 14113.0 14098.5 14093.5 14086.5 14084.5 14060.5 14048.0 14036.5 14029.0 14023.5 14015.5 14012.0 14007.0 14001.5 14209.0 14205.0 14187.0 14184.0 14166.0 14159.0 14153.0 14148.0 14137.0 14117.5 14113.0 14093.5 14089.5 14084.5 14073.0 14070.0 14064.0 14060.5 14055.5 14052.5 14048.0 14040.0 14029.0 14023.5 14015.5 14012.0 14007.0 14001.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 14000.5 13999.5 13999.5 13997.5 13996.5 13996.5 13993.0 13992.5 13992.5 13988.0 13988.0 13988.0 13985.0 13986.5 13986.5 13982.0 13981.0 13981.5 13981.5 13978.0 13978.0 13974.5 13974.5 13974.5 13970.0 13970.0 13970.0 13965.5 13965.0 13965.0 13961.5 13961.0 13961.0 13957.5 13956.0 13957.0 13956.0 13953.0 13953.5 13952.5 13953.5 13950.0 13949.0 13949.0 13949.0 13946.0 13946.0 13946.0 13942.0 13941.0 13942.0 13935.0 13935.5 13935.5 13925.0 13925.0 13925.0 13922.0 13922.0 100.0 100.0 100.0 $ CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE TDTP DATA AQUIRED ON BP EXPLORATION'S 3-09/L-28A WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #1 AND THE BCS GAI~MA RAY, ALSO SIGMA BASE PASS #1 AND THE BCS GA~A RAY, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. THIS DATA WAS AQUIRED BY WESTERN ATLAS AND PROCESSED BY GEOQUEST'S ALASKA ICS. WESTERN ATLAS'S NEUMONICS ARE USED. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION ' O01CO1 DATE · 98/02/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: FILE SUFk4ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 14201 . 0 13920.0 PDK 14211.0 13920.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH PDK REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BASE PASS #1. THERE ARE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 $ 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: ** SET TYPE - CHAN ** NA~IE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 79712 O0 000 O0 0 1 1 1 4 68 0000000000 SGMA PDK CU 79712 O0 000 O0 0 1 1 1 4 68 0000000000 RATO PDK 79712 O0 000 O0 0 1 1 1 4 68 0000000000 MSD PDK CU 79712 O0 000 O0 0 1 1 1 4 68 0000000000 BKS PDK CPS 79712 O0 000 O0 0 1 1 1 4 68 0000000000 BKL PDK CPS 79712 O0 000 O0 0 1 1 1 4 68 0000000000 SS PDK CPS 79712 O0 000 O0 0 1 1 1 4 68 0000000000 LS PDK CPS 79712 O0 000 O0 0 1 1 1 4 68 0000000000 RICS PDK DIM 79712 O0 000 O0 0 1 1 1 4 68 0000000000 RIN PDK DIM 79712 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH PDK CAPI 79712 O0 000 O0 0 1 1 1 4 68 0000000000 TENS PDK LB 79712 O0 000 O0 0 1 1 1 4 68 0000000000 CCL PDK V 79712 O0 000 O0 0 1 1 1 4 68 0000000000 RBOR PDK 79712 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 14211.000 SGMA.PDK 15.367 RATO.PDK 15.261 MSD.PDK BKS.PDK 413.434 BKL.PDK 249.128 SS.PDK 41679.352 LS.PDK RICS. PDK 12.941 RIN. PDK 9.943 GRCH. PDK -999.250 TENS.PDK CCL.PDK 0.000 RBOR.PDK 1.542 DEPT. 13920.000 SGMA.PDK 37.091 RATO.PDK 26.881 MSD.PDK BKS. PDK 321.775 BKL.PDK 144.874 SS.PDK 25298.766 LS.PDK RICS.PDK 18.518 RIN. PDK 12.051 GRCH. PDK 75.655 TENS.PDK CCL.PDK 329.870 RBOR.PDK 1.680 0.211 2730.758 400.301 0.282 942.545 14.023 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION . O01CO1 DATE . 98/02/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: **** FILE HEADER **** FILE NAM~ : EDIT .002 SERVICE : FLIC VERSION . O01CO1 DATE : 98/02/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE iVUM~ER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SOY~IARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 14208.0 13924.0 PDK 14218.0 13925.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 14210.5 14208.5 14202.0 14196.5 14192.5 14192.0 14188.5 14186.5 14183.5 14181.5 14176.0 14173.5 14173.0 14170.5 14168.0 14167.5 14162.5 14160.5 14157.5 14154.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH PDK .............. 88888.0 88886.0 14192.5 14187.5 14184.0 14182.0 14174.0 14172.5 14169.0 14163.5 14159.0 14208.5 14205.5 14201.0 14194.5 14190.5 14184.5 14180.0 14177.0 14172.5 14169.0 14159.5 14153.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 14148.5 14148.0 14147.5 14148.0 14142.5 14143.0 14140.0 14140.5 14139.0 14141.0 14135.5 14136.0 14135.0 14135.0 14129.5 14129.5 14127.0 14128.0 14124.5 14123.5 14123.5 14124.0 14120.0 14120.0 14117.5 14117.5 14116.0 14116.0 14115.5 14115.5 14113.0 14113.5 14110.5 14111.5 14108.0 14108.5 14100.5 14101.0 14094.5 14097.5 14093.0 14094.0 14090.0 14091.0 14089.0 14090.5 14086.5 14087.0 14084.5 14086.5 14082.0 14084.5 14076.0 14076.5 14072.5 14072.0 14072.0 14070.5 14070.0 14068.0 14065.5 14064.0 14064.5 14064.5 14062.0 14060.5 14061.5 14060.5 14056.5 14055.0 14049.5 14048.5 14049.5 14044.5 14043.5 14043.5 14043.0 14041.0 14039.5 14040.0 14039.0 14034.0 14034.5 14031.5 14031.0 14027.5 14026.5 14026.0 14024.0 14019.5 14017.5 14019.0 14018.5 14016.0 14013.5 14015.5 14015.5 14011.5 14010.5 14010.5 14010.5 14007.5 14006.5 14006.0 14006.0 14002.5 14001.5 14002.0 14001.5 13999.5 13999.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 13992.5 13986.0 13985 0 13982 5 13982 0 13977 0 13976 0 13975 0 13970 5 13970 0 13966 0 13965 5 13961 5 13960.0 13958.0 13956.0 13953.5 13952.0 13949.5 13947.5 13946.5 13942.5 13942.0 13936.5 13935.0 13931.5 100.0 $ 13994.0 13986.0 13981.0 13975.0 13970.5 13965.5 13961.5 13953.5 13949.0 13946.0 13941.0 13935.5 13929.5 98.0 13985.0 13981.5 13978.0 13974.5 13970.0 13965.5 13959 5 13956.5 13955 0 13949 5 13946 0 13942 0 13935 5 99. 0 REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BASE PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #2 AND GRCHBASE PASS #1, ALSO SIGMA BASE PASS #2 AND SIGMA BASE PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: TYPE REPR CODE VALUE .............................. 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NglVl~ SERV UNIT SERVICE API API API API FILE _NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 79712 O0 000 O0 0 2 1 1 4 68 0000000000 SGMA PDK CU 79712 O0 000 O0 0 2 1 1 4 68 0000000000 RATO PDK 79712 O0 000 O0 0 2 1 1 4 68 0000000000 MSD PDK CU 79712 O0 000 O0 0 2 1 1 4 68 0000000000 BKS PDK CPS 79712 O0 000 O0 0 2 1 1 4 68 0000000000 BIlL PDK CPS 79712 O0 000 O0 0 2 1 1 4 68 0000000000 SS PDK CPS 79712 O0 000 O0 0 2 1 1 4 68 0000000000 LS PDK CPS 79712 O0 000 O0 0 2 1 1 4 68 0000000000 RICS PDK DIM 79712 O0 000 O0 0 2 1 1 4 68 0000000000 RIN PDK DIM 79712 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH PDK GAPI 79712 O0 000 O0 0 2 1 1 4 68 0000000000 TENS PDK LB 79712 O0 000 O0 0 2 1 1 4 68 0000000000 CCL PDK V 79712 O0 000 O0 0 2 1 1 4 68 0000000000 RBOR PDK 79712 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 14218.000 SGMA.PDK 13.878 RATO. PDK 15.136 MSD.PDK BKS.PDK 1859.710 BKL.PDK 831.448 SS.PDK 44849.297 LS.PDK RICS.PDK 11.880 RIN. PDK 10.582 GRCH. PDK -999.250 TENS.PDK CCL.PDK 0.000 RBOR.PDK 1.494 DEPT. 13924.000 SGMA.PDK -999.250 RATO.PDK -999.250 MSD.PDK BKS. PDK -999.250 Bt~L.PDK -999.250 SS.PDK -999.250 LS.PDK RICS.PDK -999.250 RIN. PDK -999.250 GRCH. PDK 50.814 TENS.PDK CCL.PDK -999.250 RBOR.PDK -999.250 0.519 2994.550 374.681 -999.250 -999.250 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 10 **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAi~E : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ~ER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUBk4ARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 14207.5 13921.0 PDK 14216.5 13920.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 14208.5 14197.0 14192.0 14189.0 14188.0 14183.5 14181.5 14179.0 14172.5 14168.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH PDK .............. 88887.5 88884.5 14196.5 14187.0 14184.0 14182.0 14179.5 14174.0 14205.0 14190.5 14187.0 14172.5 14169.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 11 14167.5 14169.0 14160.0 14159.0 14158.5 14160.0 14156.0 14158.5 14154.0 14153.5 14147.5 14148.0 14142.0 14143.0 14140.0 14140.5 14138.5 14138.5 14141.0 14137.0 14137.0 14130.5 14132.5 14129.0 14129.5 14127.0 14128.0 14123.5 14124.0 14122.0 14122.5 14118.5 14117.5 14115.0 14115.5 14113.0 14113.0 14110.5 14111.5 14108.0 14109.0 14106.5 14107.5 14101.0 14101.0 14096.5 14099.5 14094.5 14098.5 14093.5 14094.0 14092.5 14094.0 14086.5 14086.5 14084.0 14085.5 14086.5 14081.0 14081.5 14080.0 14084.5 14075.5 14077.0 14072.0 14073.0 14070.0 14070.0 14068.0 14068.0 14063.5 14064.5 14063.5 14060.5 14060.5 14060.5 14055.5 14055.5 14055.0 14055.5 14051.0 14052.5 14048.5 14050.0 14043.0 14043.5 14033.5 14035.5 14033.0 14034.5 14031.0 14031.5 14027.5 14028.5 14025.5 14025.5 14023.5 14023.5 14021.0 14020.5 14017.5 14018.0 14015.5 14013.0 14015.0 14015.5 14011.0 14011.5 14010.5 14008.0 14007.0 14007.0 14006.5 14004.0 14003.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 12 14001.5 14001.5 14001.0 14001.5 13997.5 13996.5 13992.0 13993.5 13988.0 13988.5 13984.5 13985.5 13981.5 13982.5 13981.0 13981.0 13978.0 13979.0 13974.0 13974.5 13973.5 13974.5 13970.0 13970.5 13969.5 13970.0 13965.0 13965.5 13965.5 13957.0 13956.5 13955.0 13956.0 13954.5 13955.5 13953.0 13954.0 13949.0 13949.0 13949.5 13946.0 13946.5 13941.5 13942.5 13940.5 13941.0 13934.5 13935.5 13933.0 13935.5 13930.0 13930.5 13925.5 13925.0 13925.5 13921.5 13922.5 100.0 101.0 100.0 $ REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BASE PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS BASE #3 AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #3 AND SIGMA BASE PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 13 TYPE REPR CODE VALUE .............................. 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 79712 O0 000 O0 0 3 1 1 4 68 0000000000 SGMA PDK CU 79712 O0 000 O0 0 3 1 1 4 68 0000000000 RATO PDK 79712 O0 000 O0 0 3 1 1 4 68 0000000000 MSD PDK CU 79712 O0 000 O0 0 3 1 1 4 68 0000000000 BKS PDK CPS 79712 O0 000 O0 0 3 1 1 4 68 0000000000 BI<L PDK CPS 79712 O0 000 O0 0 3 1 1 4 68 0000000000 SS PDK CPS 79712 O0 000 O0 0 3 1 1 4 68 0000000000 LS PDK CPS 79712 O0 000 O0 0 3 1 1 4 68 0000000000 RICS PDK DIM 79712 O0 000 O0 0 3 1 1 4 68 0000000000 RIN PDK DIM 79712 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH PDK GAPI 79712 O0 000 O0 0 3 1 1 4 68 0000000000 TENS PDK LB 79712 O0 000 O0 0 3 1 1 4 68 0000000000 CCL PDK V 79712 O0 000 O0 0 3 1 1 4 68 0000000000 RBOR PDK 79712 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 14216.500 SGMA.PDK 15.261 RATO.PDK 16.900 MSD.PDK BKS.PDK 652.216 BKL.PDK 503.685 SS.PDK 42046.898 LS.PDK RICS.PDK 12.561 RIN. PDK 10.824 GRCH.PDK -999.250 TENS.PDK CCL.PDK 0.000 RBOR.PDK 1.518 DEPT. 13920.000 SGMA.PDK 36.406 RATO. PDK 27.061 MSD.PDK BKS. PDK 351.814 BKL.PDK 200.773 SS.PDK 30231.348 LS.PDK RICS.PDK 18.187 RIN. PDK 11.699 GRCH. PDK -999.250 TENS.PDK CCL.PDK 104.902 RBOR.PDK 1.628 0.470 2517. 722 484.106 O. 353 1118. 293 - 4. 683 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 14 **** FILE TRAILER **** FILE NA~E : EDIT .003 SERVICE : FLIC VERSION · O01CO1 DATE : 98/02/12 ~ REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ~ER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INCREMENT: O. 5000 FILE S02vmL~RY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 14206.5 13920.0 PDK 14216.5 13920.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888 0 14208 5 14205 0 14194 0 14189 5 14185 5 14184.5 14181.5 14181.0 14179.0 14171.0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH PDK 88890.5 88888.5 14196.5 14187.5 14183.5 14182.0 14174.0 14209.0 14205.0 14190.0 14184.5 14180.0 14177.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 15 14168.0 14165.5 14163.0 14160.5 14155.0 14154.5 14152.5 14150.0 14146.5 14142 5 14139 5 14137 5 14134 5 14128 0 14126 0 14123 0 14119 0 14116 5 14112 0 14106 5 14095 0 14092 5 14087.0 14081.0 14076.0 14068.5 14064.0 14061.0 14056.0 14052.0 14050.0 14045.5 14042.5 14034.5 14028.0 14025.5 14023.5 14019.0 14018.5 14014.0 14013.5 14011.0 14010.5 14007.5 14004.5 14002.0 14001.5 14000.0 13998.5 13992.0 13988.0 13984.5 13981.5 13981.0 13975.0 14172.0 14169.5 14166.0 14163.0 14158.5 14153.0 14148.0 14144.5 14140.5 14138.5 14136.0 14129.5 14128.0 14124.0 14120.0 14117.0 14113.0 14108.5 14098.5 14094.0 14087.0 14082.0 14076.5 14068.0 14064.5 14060.5 14048.5 14041.0 14034.5 14025.0 14018.0 14011.5 14010.0 14001.5 13998.5 13996.5 13988.0 13986.0 13981.0 13975.0 14156.0 14153.0 14115.5 14060.5 14055.0 14052.5 14049.0 14025.5 14023.5 14018.5 14012.0 14010.5 14007.0 14004.0 14001.5 13993.0 13985.5 13981.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 16 13970 5 13970 0 13965 5 13959 5 13957 5 13957 0 13955 0 13953.5 13950.0 13949.0 13947.0 13946.5 13943.0 13942.0 13935.5 13935.0 13930.0 13925.0 13922.5 100.0 $ 13970.5 13965.5 13957.5 13953.5 13949.0 13946.0 13941.0 13935.5 13930.0 13925.0 13922.5 100.0 13970.0 13965.5 13958.5 13956.5 13954.5 13949.5 13946.0 13942.0 13935.5 13925.5 100.5 REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BORAX PASS Hi. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BORAX PASS Hi AND GRCH BASE PASS Hi, ALSO SIGMA BORAX PASS HI AND SIGMA BASE PASS HI, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FO~T DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 17 TYPE REPR CODE VALUE 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 79712 O0 000 O0 0 4 1 1 4 68 0000000000 SGMA PDK CU 79712 O0 000 O0 0 4 1 1 4 68 0000000000 RATO PDK 79712 O0 000 O0 0 4 1 1 4 68 0000000000 MSD PDK CU 79712 O0 000 O0 0 4 1 1 4 68 0000000000 BKS PDK CPS 79712 O0 000 O0 0 4 1 1 4 68 0000000000 BI(L PDK CPS 79712 O0 000 O0 0 4 1 1 4 68 0000000000 SS PDK CPS 79712 O0 000 O0 0 4 1 1 4 68 0000000000 LS PDK CPS 79712 O0 000 O0 0 4 1 1 4 68 0000000000 RICS PDK DIM 79712 O0 000 O0 0 4 1 1 4 68 0000000000 RIN PDK DIM 79712 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH PDK GAPI 79712 O0 000 O0 0 4 1 1 4 68 0000000000 TENS PDK LB 79712 O0 000 O0 0 4 1 1 4 68 0000000000 CCL PDK V 79712 O0 000 O0 0 4 1 1 4 68 0000000000 RBOR PDK 79712 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 14216.500 SGMA.PDK 18.056 RATO.PDK 15.683 MSD.PDK BKS.PDK 375.659 BKL. PDK 331.854 SS.PDK 22581.301 LS.PDK RICS.PDK 17.930 RIN. PDK 10.285 GRCH. PDK -999.250 TENS.PDK CCL.PDK 1500.000 RBOR.PDK 1.701 O. 428 1446. 033 347.273 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 18 **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 5 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 14210.5 13920.5 PDK 14220.5 13921.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS ~ER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH PDK 88888.0 88890.5 88888.5 14204.5 14205.0 14194.5 14197.0 14190.5 14192.5 14185.5 14187.0 14184.5 14184.5 14181.5 14183.5 14180.0 14179.0 14182.0 14177.0 14177.0 14175.5 14171.0 14174.0 14169.0 14167.5 14165.5 14169.0 14165.5 14163.0 14165.5 14161.5 14162.5 14158.5 14161.5 14154.0 14158.0 14152.5 14153.0 14150.5 14153.0 14146.5 14148.5 14145.0 14146.0 14143.5 14143.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 19 14140.0 14139.5 14136.5 14131.0 14128.5 14123.0 14119.0 14116.5 14112.5 14108.5 14102.0 14101.0 14094.5 14092.5 14091.5 14086.5 14083.5 14082.0 14081.0 14075.5 14070.5 14070.0 14068.5 14064.0 14060.5 14060.0 14055.5 14048.5 14040.0 14030.5 14029.5 14024.5 14021.5 14020.0 14018.5 14014.0 14012.5 14009.5 14007.0 14001.5 14001.0 13988.5 13987.0 13983.5 13981.5 13976.5 13973 0 13970 0 13969 5 13965 5 13964 5 13959 5 13956.0 13954.0 13953.0 14140.5 14129.5 14124.0 14120.0 14117.5 14113.5 14103.5 14097.5 14094.0 14086.5 14085.0 14081.5 14076.5 14072.0 14067.5 14064.5 14060.5 14039.0 14029.0 14018.0 14011.5 14006.5 14001.5 13986.5 13981.0 13974.0 13970.5 13965.5 13959.5 13955.5 13954.0 14140.0 14137.0 14128.5 14107.5 14102.5 14094.0 14092.0 14083.5 14080.5 14076.5 14069.5 14060.5 14055.0 14049.5 14029.0 14025.5 14020.5 14018.5 14013.5 14010.5 14007.0 14001.5 13990.5 13985.0 13977.5 13970.0 13965.5 13958.0 13955.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 2O 13952.0 13949.5 13948.5 13946.0 13945 5 13941 5 13941 0 13935 5 13934 0 13929 0 13924 5 13920 5 100 0 $ 13949.0 13946.0 13941.0 13935.5 13930.0 13925.0 13921.0 100.5 13953.5 13949.5 13946.0 13942.0 13937.0 13925.5 101.0 REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BORAX PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BORAX PASS #2 AND GRCH BASE PASS #1, ALSO SIGMA BORAX PASS #2 AND SIGMA BASE PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 21 ** SET TYPE - CHAN ** N~ SERV UNIT SERVICE g-PI API API API FILE NUmB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 79712 O0 000 O0 0 5 1 1 4 68 0000000000 SGSIA PDK CU 79712 O0 000 O0 0 5 1 1 4 68 0000000000 RATO PDK 79712 O0 000 O0 0 5 1 1 4 68 0000000000 MSD PDK CU 79712 O0 000 O0 0 5 1 1 4 68 0000000000 BKS PDK CPS 79712 O0 000 O0 0 5 1 1 4 68 0000000000 BKL PDK CPS 79712 O0 000 O0 0 5 1 1 4 68 0000000000 SS PDK CPS 79712 O0 000 O0 0 5 1 1 4 68 0000000000 LS PDK CPS 79712 O0 000 O0 0 5 1 1 4 68 0000000000 RICS PDK DIM 79712 O0 000 O0 0 5 1 1 4 68 0000000000 RIN PDK DIM 79712 O0 000 O0 0 5 1 1 4 68 0000000000 GRCHPDK GAPI 79712 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PDK LB 79712 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PDK V 79712 O0 000 O0 0 5 1 1 4 68 0000000000 RBOR PDK 79712 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 14220.000 SGMA.PDK 15.125 RATO.PDK 13.188 MSD.PDK BKS.PDK 405.333 BKL.PDK 448.397 SS.PDK 24366.102 LS.PDK RICS.PDK 16.349 RIN. PDK 10.141 GRCH. PDK -999.250 TENS.PDK CCL.PDK 1500.000 RBOR.PDK 1.704 DEPT. 13920.500 SGMA.PDK -999.250 RATO.PDK -999.250 MSD.PDK BKS.PDK -999.250 BKL.PDK -999.250 SS.PDK -999.250 LS.PDK RICS.PDK -999.250 RIN. PDK -999.250 GRCH. PDK 89.471 TENS.PDK CCL.PDK -999.250 RBOR.PDK -999.250 0.315 1836.785 153.401 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION · O01CO1 DATE : 98/02/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 22 **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE . FLIC VERSION : O01CO1 DATE : 98/02/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NU~fBER: 6 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 6 DEPTH INCRE~fENT: 0.5000 FILE SU~ff4ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 14209.5 13920.5 PDK 14219.5 13921.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 14210.0 14195.0 14194.5 14187.0 14186.0 14185.0 14181.5 14179.5 14171.5 14169.0 14166.5 14163.5 14159.5 14159.0 14155.5 14153.5 14146.5 14146.0 14141.5 14139.5 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH PDK 88889.5 88887.5 14209.5 14196.5 14195.5 14187.0 14187.5 14184.5 14184.0 14182.0 14179.5 14174.0 14172.0 14169.0 14166.0 14159.5 14161.5 14158.5 14153.0 14148.0 14147.0 14143.0 14140.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 23 14137.0 14139.5 14135.0 14136.0 14137.0 14132.5 14133.5 14128.0 14129.5 14123.0 14124.0 14119.0 14120.0 14117.0 14117.5 14112.5 14113.5 14110.0 14111.0 14107.5 14108.5 14099.0 14102.0 14096.0 14100.0 14095.0 14098.0 14092.5 14094.0 14089.5 14090.5 14087.0 14086.5 14089.0 14084.0 14085.5 14081.5 14084.5 14080.5 14081.5 14075.5 14077.0 14073.0 14073.0 14061.0 14060.5 14060.5 14060.5 14056.0 14055.5 14051.5 14052.5 14049.0 14048.5 14042.0 14041.5 14033.5 14034.5 14025.5 14026.0 14023.5 14023.5 14022.5 14023.5 14018.5 14018.5 14018.0 14018.0 14015.5 14016.0 14011.0 14010.5 14007.5 14006.5 14006.0 14005.5 14004.5 14003.5 14001.5 14001.5 14001.5 13999.5 13998.5 13999.0 13997.0 13993.5 13993.5 13987.5 13988.0 13984.5 13985.5 13984.0 13986.0 13981.5 13981.0 13975.0 13975.0 13973.5 13974.0 13971.0 13970.5 13969.5 13969.5 13965.5 13965.5 13965.0 13965.0 13957.5 13956.5 13955.5 13955.0 13953.5 13953.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 24 13949.5 13949.0 13949.0 13947.0 13946.5 13946.5 13943.0 13940.5 13941.0 13936.0 13930.0 13925.0 13921.5 100.0 100.5 $ 13949.5 13946.0 13942.5 13936.0 13930.5 13925.0 13922.5 101.0 REMARKS: THIS FILE CONTAINS CASED HOLE TDTP FLUSH PASS Hi. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH FLUSH PASS HI AND GRCH BASE PASS HI, ALSO SIGMA FLUSH PASS Hi AND SIGMA BASE PASS HI, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 25 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 79712 O0 000 O0 0 6 1 1 4 68 0000000000 SGMA PDK CU 79712 O0 000 O0 0 6 1 1 4 68 0000000000 RATO PDK 79712 O0 000 O0 0 6 1 1 4 68 0000000000 MSD PDK CU 79712 O0 000 O0 0 6 1 1 4 68 0000000000 BKS PDK CPS 79712 O0 000 O0 0 6 1 1 4 68 0000000000 BKL PDK CPS 79712 O0 000 O0 0 6 1 1 4 68 0000000000 SS PDK CPS 79712 O0 000 O0 0 6 1 1 4 68 0000000000 LS PDK CPS 79712 O0 000 O0 0 6 1 1 4 68 0000000000 RICS PDK DIM 79712 O0 000 O0 0 6 1 1 4 68 0000000000 RIN PDK DIM 79712 O0 000 O0 0 6 1 1 4 68 0000000000 GRCH PDK GAPI 79712 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PDK LB 79712 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PDK V 79712 O0 000 O0 0 6 1 1 4 68 0000000000 RBOR PDK 79712 O0 000 O0 0 6 1 1 4 68 0000000000 * * DA TA * * DEPT. 14219.500 SGMA.PDK 15.295 RATO. PDK 13.979 MSD. PDK BKS.PDK 366.990 BKL.PDK 634.234 SS.PDK 34818.500 LS.PDK RICS. PDK 12.046 RIN. PDK 9.931 GRCH. PDK -999.250 TENS.PDK CCL.PDK 1500.000 RBOR.PDK 1.535 0.377 2477.125 194.092 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION · O01CO1 DATE : 98/02/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 26 FILE HEADER FILE IgIIM~ER: 7 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, 3, PDK $ REMARKS THIS FILE CONTAINS THE ARITHMETIC AVERAGE OF PASSES 1,2, &3. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 79712 O0 000 O0 0 7 1 1 4 68 0000000000 SGMA PNAV CU 79712 O0 000 O0 0 7 1 1 4 68 0000000000 RATO PNAV 79712 O0 000 O0 0 7 1 1 4 68 0000000000 MSD PNAV CU 79712 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 27 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) BKS PDK CPS 79712 O0 000 O0 0 7 1 1 4 68 0000000000 BKL PDK CPS 79712 O0 000 O0 0 7 1 1 4 68 0000000000 SS PNAV CPS 79712 O0 000 O0 0 7 1 1 4 68 0000000000 LS PNAV CPS 79712 O0 000 O0 0 7 1 1 4 68 0000000000 RICS PNAV DIM 79712 O0 000 O0 0 7 1 1 4 68 0000000000 RIN PNAV DIM 79712 O0 000 O0 0 7 1 1 4 68 0000000000 GRCH PDK GAPI 79712 O0 000 O0 0 7 1 1 4 68 0000000000 RBOR PNAV 79712 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. BKS.PDK RICS.PNAV 14211. 000 SGMA. PNAV 413. 434 Bt~L. PDK 13. 047 RIN. PNAV 15.842 RATO. PNAV 15.270 MSD. PNAV 0.201 249.128 SS.PNAV 42159.016 LS.PNAV 2750.140 10.183 GRCH. PDK -999.250 RBOR.PNAV 1.555 DEPT. 13920.000 SGMA.PNAV -999.250 RATO. PNAV -999.250 MSD. PNAV -999.250 BKS.PDK 321.775 BKL.PDK 144.874 SS.PNAV -999.250 LS.PNAV -999.250 RICS.PNAV -999.250 RIN. PNAV -999.250 GRCH. PDK 75.655 RBOR.PNAV -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE · FLIC VERSION · O01CO1 DATE · 98/02/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION ' O01CO1 DATE : 98/02/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER RAW CURVES LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 28 Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SU~94ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 14236.0 13908.5 PDK $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR, PDK, CCL THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) '. FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): O1-FEB-98 FSYS REV JO01 1157 O1-FEB-98 14526.0 13920.0 14220.0 TOOL NUMBER 2725XA PDK-iOO/GR/CC 14850.0 PRODUCED/BORAX THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 29 FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4500 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): REMARKS: REFERNCE LOG, SBT (13-APR-95) FIRST PASS LOGGED WITH 20 BBLS BORAX AWAY SECOND PASS LOGGED WITH 50 BBLS BORAX AWAY THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 80 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 * * SET TYPE - CHAN * * NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 79712 O0 000 O0 0 8 1 1 4 68 0000000000 SGMA PS1 SU 79712 O0 000 O0 0 8 1 1 4 68 0000000000 RATO PS1 79712 O0 000 O0 0 8 1 1 4 68 0000000000 MSD PS1 SU 79712 O0 000 O0 0 8 1 1 4 68 0000000000 BKS PS1 CPS 79712 O0 000 O0 0 8 1 1 4 68 0000000000 BKL PS1 CPS 79712 O0 000 O0 0 8 1 1 4 68 0000000000 SS PS1 CPS 79712 O0 000 O0 0 8 1 1 4 68 0000000000 LS PS1 CPS 79712 O0 000 O0 0 8 1 1 4 68 0000000000 RICS PS1 DIM 79712 O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 30 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) RIN PS1 DIM 79712 O0 000 O0 0 8 1 1 4 68 0000000000 GR PS1 API 79712 O0 000 O0 0 8 1 1 4 68 0000000000 TEN PS1 LBF 79712 O0 000 O0 0 8 1 1 4 68 0000000000 CCL PS1 V 79712 O0 000 O0 0 8 1 1 4 68 0000000000 SPD PS1 FPM 79712 O0 000 O0 0 8 1 1 4 68 0000000000 G1 PSl CPS 79712 O0 000 O0 0 8 1 1 4 68 0000000000 G2 PS1 CPS 79712 O0 000 O0 0 8 1 1 4 68 0000000000 MON PS1 CPS 79712 O0 000 O0 0 8 1 1 4 68 0000000000 CSS PS1 API 79712 O0 000 O0 0 8 1 1 4 68 0000000000 ISS PS1 CPS 79712 O0 000 O0 0 8 1 1 4 68 0000000000 RBOR PS1 79712 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. 14220.000 SGMA.PS1 13.248 RATO.PS1 13.141 MSD.PS1 0.229 BKS.PS1 912.040 BKL.PS1 166.443 SS.PSi 43054.438 LS.PS1 3282.361 RICS.PS1 12.054 RIN. PS1 10.427 GR.PS1 120.997 TEN. PSI 520.034 CCL.PS1 800.000 SPD.PS1 899.910 Gl.PS1 17407.332 G2.PS1 7297.551 MON. PS1 2121.640 CSS.PS1 29189.691 ISS.PS1 351858.500 RBOR.PS1 1.503 ** END OF DATA **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .009 SERVICE ' FLIC VERSION : O01CO1 DATE : 98/02/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 31 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SO?4MARY VENDOR TOOL CODE START DEPTH STOP DEPTH 14243.0 13915.5 PDK $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR, PDK, CCL THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): O1-FEB-98 FSYS REV JO01 1157 O1-FEB-98 14526.0 13920.0 14220.0 TOOL NUMBER 2725XA PDK-iOO/GR/CC 14850.0 PRODUCED/BORAX THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 32 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4500 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): REMARKS: REFERNCE LOG, SBT (13-APR-95) FIRST PASS LOGGED WITH 20 BBLS BORAX AWAY SECOND PASS LOGGED WITH 50 BBLS BORAX AWAY THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 * * SET TYPE - CHAN * * NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 79712 O0 000 O0 0 9 1 1 4 68 0000000000 SGMA PS2 SU 79712 O0 000 O0 0 9 1 1 4 68 0000000000 RATO PS2 79712 O0 000 O0 0 9 1 1 4 68 0000000000 MSD PS2 SU 79712 O0 000 O0 0 9 1 1 4 68 0000000000 BKS PS2 CPS 79712 O0 000 O0 0 9 1 1 4 68 0000000000 BKL PS2 CPS 79712 O0 000 O0 0 9 1 1 4 68 0000000000 SS PS2 CPS 79712 O0 000 O0 0 9 1 1 4 68 0000000000 LS PS2 CPS 79712 O0 000 O0 0 9 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 33 NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) RICS PS2 DIM 79712 O0 000 O0 0 9 1 1 4 68 0000000000 RIN PS2 DIM 79712 O0 000 O0 0 9 1 1 4 68 0000000000 GR PS2 API 79712 O0 000 O0 0 9 1 1 4 68 0000000000 TEN PS2 LBF 79712 O0 000 O0 0 9 1 1 4 68 0000000000 CCL PS2 V 79712 O0 000 O0 0 9 1 1 4 68 0000000000 SPD PS2 FPM 79712 O0 000 O0 0 9 1 1 4 68 0000000000 G1 PS2 CPS 79712 O0 000 O0 0 9 1 1 4 68 0000000000 G2 PS2 CPS 79712 O0 000 O0 0 9 1 1 4 68 0000000000 MON PS2 CPS 79712 O0 000 O0 0 9 1 1 4 68 0000000000 CSS PS2 API 79712 O0 000 O0 0 9 1 1 4 68 0000000000 ISS PS2 CPS 79712 O0 000 O0 0 9 1 1 4 68 0000000000 RBOR PS2 79712 O0 000 O0 0 9 1 1 4 68 0000000000 SGNT PS2 79712 O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA ** DEPT. 14220.000 SGMA.PS2 13.878 RATO.PS2 15.136 MSD.PS2 BKS.PS2 1859.710 BKL.PS2 831.448 SS.PS2 44849.297 LS.PS2 RICS.PS2 11.880 RIN. PS2 10.582 GR.PS2 232.754 TEN. PS2 CCL.PS2 0.000 SPD.PS2 839.916 Gl.PS2 17951.797 G2.PS2 MON. PS2 2139.834 CSS.PS2 30687.859 ISS.PS2 364577.000 RBOR.PS2 SGNT. PS2 8.788 0.519 2994.550 374.681 7372.160 1.494 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE · FLIC VERSION : O01CO1 DATE : 98/02/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .010 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 34 FILE HEADER FILE i~JMBER 10 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUN~L~RY VENDOR TOOL CODE START DEPTH STOP DEPTH 14244.0 13908.5 PDK $ LOG H~ER DATA DATE LOGGED: SOFTWARE VERSION: TI~E LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR , PDK , CCL THERMAL DECAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): O1-FEB-98 FSYS REV JO01 1157 O1-FEB-98 14526.0 13920.0 14220.0 TOOL NUMBER 2725XA PDK-IOO/GR/CC 14850.0 PRODUCED/BORAX THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 35 BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4500 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): REMARKS: REFERNCE LOG, SBT (13-APR-95) FIRST PASS LOGGED WITH 20 BBLS BORAX AWAY SECOND PASS LOGGED WITH 50 BBLS BORAX AWAY THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 79712 O0 000 O0 0 10 1 1 4 68 0000000000 SGMA PS3 SU 79712 O0 000 O0 0 10 1 1 4 68 0000000000 RATO PS3 79712 O0 000 O0 0 10 1 1 4 68 0000000000 MSD PS3 SU 79712 O0 000 O0 0 10 1 1 4 68 0000000000 BKS PS3 CPS 79712 O0 000 O0 0 10 1 1 4 68 0000000000 BKL PS3 CPS 79712 O0 000 O0 0 10 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 3 6 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SS PS3 CPS 79712 O0 000 O0 0 10 1 1 4 68 0000000000 LS PS3 CPS 79712 O0 000 O0 0 10 1 1 4 68 0000000000 RICS PS3 DIM 79712 O0 000 O0 0 10 1 1 4 68 0000000000 RIN PS3 DIM 79712 O0 000 O0 0 10 1 1 4 68 0000000000 GR PS3 API 79712 O0 000 O0 0 10 1 1 4 68 0000000000 TEN PS3 LBF 79712 O0 000 O0 0 10 1 1 4 68 0000000000 CCL PS3 V 79712 O0 000 O0 0 10 1 1 4 68 0000000000 SPD PS3 FPM 79712 O0 000 O0 0 10 1 1 4 68 0000000000 G1 PS3 CPS 79712 O0 000 O0 0 10 1 1 4 68 0000000000 G2 PS3 CPS 79712 O0 000 O0 0 10 1 1 4 68 0000000000 MON PS3 CPS 79712 O0 000 O0 0 10 1 1 4 68 0000000000 CSS PS3 API 79712 O0 000 O0 0 10 1 1 4 68 0000000000 ISS PS3 CPS 79712 O0 000 O0 0 10 1 1 4 68 0000000000 RBOR PS3 79712 O0 000 O0 0 10 1 1 4 68 0000000000 SGNT PS3 79712 O0 000 O0 0 10 1 1 4 68 0000000000 ** DATA ** DEPT. 14220.000 SGMA.PS3 15.261 RATO.PS3 16.900 MSD.PS3 0.470 BKS.PS3 652.216 BKI~.PS3 503.685 SS.PS3 42046.898 LS. PS3 2517.722 RICS.PS3 12.561 RIN. PS3 10.824 GR.PS3 130.269 TEN. PS3 484.106 CCL.PS3 0.000 SPD. PS3 959.904 Gl.PS3 15401.430 G2.PS3 5870.703 MON. PS3 2146.373 CSS.PS3 28186.016 ISS.PS3 354039.188 RBOR.PS3 1.518 SGNT. PS3 9.634 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .010 SERVICE ·FLIC VERSION ·O01CO1 DATE : 98/02/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 37 FILE HEADER FILE NY]MBER 11 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SUN~4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 14235.0 13907.5 PDK $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR , PDK, CCL THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): O1-FEB-98 FSYS REV JO01 1157 O1-FEB-98 14526.0 13920.0 14220.0 TOOL NUMBER 2725XA PDK-IOO/GR/CC 14850.0 PRODUCED/BORAX THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 38 BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4500 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): REMARKS: REFERNCE LOG, SBT (13-APR-95) FIRST PASS LOGGED WITH 20 BBLS BORAX AWAY SECOND PASS LOGGED WITH 50 BBLS BORAX AWAY THIS FILE CONTAINS THE RAW DATA FOR BORAX PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB * * .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 79712 O0 000 O0 0 11 1 1 4 68 0000000000 SGMA BX1 SU 79712 O0 000 O0 0 11 1 1 4 68 0000000000 RATO BX1 79712 O0 000 O0 0 11 1 1 4 68 0000000000 MSD BX1 SU 79712 O0 000 O0 0 11 1 1 4 68 0000000000 BKS BX1 CPS 79712 O0 000 O0 0 11 1 1 4 68 0000000000 BKL BX1 CPS 79712 O0 000 O0 0 11 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 39 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SS BX1 CPS 79712 O0 000 O0 0 11 1 1 4 LS BX1 CPS 79712 O0 000 O0 0 11 1 1 4 RICS BX1 DIM 79712 O0 000 O0 0 11 1 1 4 RIN BX1 DIM 79712 O0 000 O0 0 11 1 1 4 GR BX1 API 79712 O0 000 O0 0 11 1 1 4 TEN BX1 LBF 79712 O0 000 O0 0 11 1 1 4 CCL BX1 V 79712 O0 000 O0 0 11 1 1 4 SPD BX1 FPM 79712 O0 000 O0 0 11 1 1 4 G1 BX1 CPS 79712 O0 000 O0 0 11 1 1 4 G2 BX1 CPS 79712 O0 000 O0 0 11 1 1 4 MON BX1 CPS 79712 O0 000 O0 0 11 1 1 4 CSS BX1 API 79712 O0 000 O0 0 11 1 1 4 ISS BX1 CPS 79712 O0 000 O0 0 11 1 1 4 RBOR BX1 79712 O0 000 O0 0 11 1 1 4 SGNTBX1 79712 O0 000 O0 0 11 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. BKS.BX1 RICS.BX1 CCL.BX1 MON. BX1 SGNT.BX1 14220.000 SGMA.BX1 13.390 RATO.BX1 12.374 MSD.BX1 486.720 BKL.BX1 569.741 SS.BX1 29967.250 LS.BX1 14.142 RIN. BX1 10.107 GR.BX1 0.000 TEN. BX1 1500.000 SPD.BX1 1326.420 G1.BX1 12823.758 G2.BX1 0.000 CSS.BX1 21017.742 ISS.BX1 297223.500 RBOR.BX1 8.486 0.342 2426.970 405.797 5355.988 1.636 ** END OF DATA ** **** FILE TRAILER **** FILE NAN~ : EDIT .011 SERVICE · FLIC VERSION · O01CO1 DATE · 98/02/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .012 SERVICE · FLIC VERSION · O01CO1 DATE : 98/02/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 40 FILE HEADER FILE 1V-UMBER 12 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 5 DEPTH INCREMENT: O . 5000 FILE SUI~Y VENDOR TOOL CODE START DEPTH STOP DEPTH 14235.0 13907.5 PDK $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR , PDK, CCL THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): O1 -FEB-98 FSYS REV JO01 1157 O1 -FEB-98 14526.0 13920.0 14220.0 TOOL NUMBER 2725XA PDK- 100/GR/CC 14850.0 PRODUCED/BORAX THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 41 BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4500 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): REMARKS: REFERNCE LOG, SBT (13-APR-95) FIRST PASS LOGGED WITH 20 BBLS BORAX AWAY SECOND PASS LOGGED WITH 50 BBLS BORAX AWAY THIS FILE CONTAINS THE RAW DATA FOR BORAX PASS #1. $ LIS FO~T DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 2 3 4 5 66 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 66 0 66 0 73 84 66 1 0.5 FT 12 0 FT 68 1 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 79712 O0 000 O0 0 12 1 1 4 68 0000000000 SGMA BX2 SU 79712 O0 000 O0 0 12 1 1 4 68 0000000000 RATO BX2 79712 O0 000 O0 0 12 1 1 4 68 0000000000 MSD BX2 SU 79712 O0 000 O0 0 12 1 1 4 68 0000000000 BKS BX2 CPS 79712 O0 000 O0 0 12 1 1 4 68 0000000000 BK~ BX2 CPS 79712 O0 000 O0 0 12 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 42 NA~ZE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SS BX2 CPS 79712 O0 000 O0 0 12 1 1 4 LS BX2 CPS 79712 O0 000 O0 0 12 1 1 4 RICS BX2 DIM 79712 O0 000 O0 0 12 1 1 4 RIN BX2 DIM 79712 O0 000 O0 0 12 1 1 4 GR BX2 API 79712 O0 000 O0 0 12 1 1 4 TEN BX2 LBF 79712 O0 000 O0 0 12 1 1 4 CCL BX2 V 79712 O0 000 O0 0 12 1 1 4 SPD BX2 FPM 79712 O0 000 O0 0 12 1 1 4 G1 BX2 CPS 79712 O0 000 O0 0 12 1 1 4 G2 BX2 CPS 79712 O0 000 O0 0 12 1 1 4 MON BX2 CPS 79712 O0 000 O0 0 12 1 1 4 CSS BX2 API 79712 O0 000 O0 0 12 1 1 4 ISS BX2 CPS 79712 O0 000 O0 0 12 1 1 4 RBOR BX2 79712 O0 000 O0 0 12 1 1 4 SGNT BX2 79712 O0 000 O0 0 12 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. BKS.BX2 RICS.BX2 CCL.BX2 MON. BX2 SGNT.BX2 14220.000 SGMA.BX2 14.646 RATO.BX2 12.649 MSD.BX2 469.402 BKL.BX2 513.402 SS.BX2 24580.379 LS.BX2 16.268 RIN. BX2 10.057 GR.BX2 0.000 TEN. BX2 1500.000 SPD.BX2 1319.868 G1.BX2 9521.371 G2.BX2 0.000 CSS.BX2 17075.063 ISS.BX2 277775.250 RBOR.BX2 9.258 0.301 1937. 256 162. 895 3628. 642 1. 697 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .012 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .013 SERVICE : FLIC VERSION · O01CO1 DATE : 98/02/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 43 FILE HEADER FILE NUMBER 13 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 6 DEPTH INCRE~!ENT: 0.5000 FILE SU~LARY VENDOR TOOL CODE START DEPTH PDK 14236.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH 13908.5 O1-FEB-98 FSYS REV JO01 1157 O1-FEB-98 14526.0 13920.0 14220.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR, PDK, CCL THERMAL DECAY $ TOOL NUMBER 2725XA PDK-IOO/GR/CC BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 14850.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PRODUCED/BORAX NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 44 BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4500 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): REMARKS: REFERNCE LOG, SBT (i3-APR-95) FIRST PASS LOGGED WITH 20 BBLS BORAX AWAY SECOND PASS LOGGED WITH 50 BBLS BORAX AWAY THIS FILE CONTAINS THE RAW DATA FOR FLUSH PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 79712 O0 000 O0 0 13 1 1 4 68 0000000000 SGMA FP1 SU 79712 O0 000 O0 0 13 1 1 4 68 0000000000 RATO FP1 79712 O0 000 O0 0 13 1 1 4 68 0000000000 MSD FP1 SU 79712 O0 000 O0 0 13 1 1 4 68 0000000000 BKS FP1 CPS 79712 O0 000 O0 0 13 1 1 4 68 0000000000 BtCL FP1 CPS 79712 O0 000 O0 0 13 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 45 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SS FP1 CPS 79712 O0 000 O0 0 13 1 1 4 LS FP1 CPS 79712 O0 000 O0 0 13 1 1 4 RICS FP1 DIM 79712 O0 000 O0 0 13 1 1 4 RIN FP1 DIM 79712 O0 000 O0 0 13 1 1 4 GR FP1 API 79712 O0 000 O0 0 13 1 1 4 TEN FP1 LBF 79712 O0 000 O0 0 13 1 1 4 CCL FP1 V 79712 O0 000 O0 0 13 1 1 4 SPD FP1 FPM 79712 O0 000 O0 0 13 1 1 4 G1 FP1 CPS 79712 O0 000 O0 0 13 1 1 4 G2 FP1 CPS 79712 O0 000 O0 0 13 1 1 4 MON FP1 CPS 79712 O0 000 O0 0 13 1 1 4 CSS FP1 API 79712 O0 000 O0 0 13 1 1 4 ISS FP1 CPS 79712 O0 000 O0 0 13 1 1 4 RBOR FP1 79712 O0 000 O0 0 13 1 1 4 SGNT FP1 79712 O0 000 O0 0 13 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. BKS.FP1 RICS.FP1 CCL.FP1 MON. FP1 SGNT.FP1 14220.000 SGMA.FP1 15.295 RATO.FP1 13.979 MSD.FP1 366.990 BKL.FP1 634.234 SS.FP1 34818.500 LS.FP1 12.046 RIN. FP1 9.931 GR.FP1 96.104 TEN. FP1 1500.000 SPD.FP1 1259.875 G1.FP1 12593.551 G2.FP1 0.000 CSS.FP1 23438.465 ISS.FP1 282338.438 RBOR.FP1 9.655 0.377 2477.125 194.092 4703.691 1.535 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .013 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : * * * * TAPE TRAILER * * * * SERVICE NAME : EDIT DATE : 98/02/12 ORIGIN ' FLIC TAPE NAME : 98082 CONTINUATION # : 1 PREVIOUS TAPE : CO~iENT : BP EXPLORATION, 3-09/L-28A, ENDICOTT, API# 50-029-21780-01 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-FEB-1998 13:23 PAGE: 46 **** REEL TRAILER **** SERVICE NA~fE : EDIT DATE : 98/02/12 ORIGIN : FLIC REEL NAME : 98082 CONTINUATION # : PREVIOUS REEL : COf4~IENT : BP EXPLORATION, 3-09/L-28A, ENDICOTT, API# 50-029-21780-01 , Z 0 ,-.. ¢- Tape Subfile 2 is type: LIS TAPE HEADER ENDICOTT UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 3-09/L-28A 500292178001 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 17-APR-95 6397.02 J. DAHL SEE REMARKS 8 liN 17E 2530 838 56.00 56.00 14.50 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 9.625 10520.0 3RD STRING 7.000 12638.0 PRODUCTION STRING 5.000 14553.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH $ SBT GRCH 1 1 13-APR-95 WESTERN ATLAS LOGGING SERVICES EQUIVALENT UNSHIFTED DEPTH 47.00 26.00 18.00 REMARKS: Marked Line GR/SBT. WITNESSED BY: J. POWERS, G. MCBRIDE, & J. CARLILE *** THIS IS THE DEPTH REFERENCE FOR THIS WELL *** PASS 1 (MAIN PASS) WAS NOT DEPTH SHIFTED SINCE THE MAIN PASS IS THE DEPTH REFERENCE FOR THIS WELL. LOG TIED TO WIRELINE MARKS. FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 12100.0 14484.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 BASELINE DEPTH $ REMARKS: EQUIVALENT UNSHIFTED DEPTH PASS 1 (MAIN PASS). THE GAMMA RAY FROM THIS PASS IS THE DEPTH REFERENCE FOR THIS WELL. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 3-09/L-28A : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GRCH GR 68 1 GAPI 2 TENS GR 68 1 LB * DATA RECORD (TYPE# 0) Total Data Records: 59 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 21 990 60 6 4 4 10 579 41 1 1014 BYTES * Tape File Start Depth = 14545.000000 Tape File End Depth = 12097.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 14692 datums Tape Subfile: 2 150 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 START DEPTH 14255.0 STOP DEPTH 14483.0 files. (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GRCH 14260.0 14258.0 14266.5 14264.5 14271.0 14269.0 14275.0 14273.0 14280.0 14278.0 14297.0 14295.0 14301.5 14299.5 14330.5 14328.5 14340.5 14338.5 14369.0 14367.0 14375.5 14374.0 14384.0 14382.5 14405.5 14404.0 14415.5 14414.0 14426.5 14425.0 14430.5 14429.5 14460.0 14459.5 14464.5 14464.0 14467.5 14466.5 14470.0 14469.0 14474.5 14473.5 14478.5 14477.5 $ REMARKS: PASS 2 (REPEAT PASS). TENS WAS SHIFTED WITH GRCH. / ? ?MATCH1. OUT $ CN : BP EXPLORATION WN : 3-09/L-28A FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) (ALASKA) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GRCH GR 68 1 GAPI 2 TENS GR 68 1 LB * DATA RECORD (TYPE~ 0) Total Data Records: API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 66 264 36 0 4 4 66 264 36 0 1014 BYTES * Tape File Start Depth = 14570.000000 Tape File End Depth = 14250.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 1924 datums Tape Subfile: 3 62 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12099.0 $ LOG HEADER DATA STOP DEPTH 14500.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL GR ACC CENT SBT CENT VDL CENT $ CASING COLLAR LOC. GAMMA RAY ACOUSTILOG COMMON CENTROLLER WTS SEGMENTED BOND TOOL CENTROLLER WTS VDL SUB CENTROLLER WTS BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX'. MATRIX DENSITY: 13-APR-95 FSYS REV. J001 VER. 1.1 946 13-APR-95 14553.0 14529.0 12100.0 14521.0 1500.0 YES TOOL NUMBER 2330XA 1309XA 1633XA 1424XA 1424PA .000 14553.0 .0 POLYMER .00 .0 .0 0 .0 .000 .000 .000 .0 .00 HOLE CORRECTION (IN): . 000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): .0 .0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 0 FAR COUNT RATE HIGH SCALE (CPS) : 0 NEAR COUNT RATE LOW SCALE (CPS) : 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): .0 REMARKS: PASS 1 (MAIN PASS). $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 3-09/L-28A : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 2 CCL GR 68 3 SPD GR 68 4 TEN GR 68 5 TTEN GR 68 1 GAPI 4 1 4 1 F/MN 4 1 LB 4 1 LB 4 4 21 990 60 6 4 26 165 19 6 4 76 115 41 1 4 10 579 41 1 4 10 579 41 1 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 234 Tape File Start Depth = 14545.000000 Tape File End Depth = 12097.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 73451 datums Tape Subfile: 4 312 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 14255.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH 14524.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL GR ACC CENT SBT CENT VDL CENT $ CASING COLLAR LOC. GAMMA RAY ACOUSTILOG COMMON CENTROLLER WTS SEGMENTED BOND TOOL CENTROLLER WTS VDL SUB CENTROLLER WTS BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX' · MATRIX DENSITY: 13-APR-95 FSYS REV. J001 VER. 1.1 759 13-APR-95 14553.0 14529.0 12100.0 14521.0 1500.0 YES TOOL NUMBER 2330XA 1309XA 1633XA 1424XA 1424PA .000 14553.0 .0 POLYMER .00 .0 .0 0 .0 .000 .000 .000 .0 .00 HOLE CORRECTION (IN) : . 000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): .0 .0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): .0 REMARKS: PASS 2 (REPEAT PASS). $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 3-09/L-28A : ENDICOTT : NORTH SLOPE · ALASKA · * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 2 CCL GR 68 3 SPD GR 68 4 TEN GR 68 5 TTEN GR 68 1 GAPI 4 1 4 1 F/MN 4 1 LB 4 1 LB 4 4 21 990 60 6 4 26 165 19 6 4 76 115 41 1 4 10 579 41 1 4 10 579 41 1 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 31 Tape File Start Depth = 14570.000000 Tape File End Depth = 14250.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 9611 datums Tape Subfile: 5 109 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 6 is type: LIS 95/ 4/17 01 **** REEL TRAILER **** 95/ 4/18 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 18 APR 95 10:4la Elapsed execution time = 6.70 seconds. SYSTEM RETURN CODE = 0 Tape Subfile 2 is type: LIS TAPE HEADER ENDICOTT UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING RUN 1 6397.00 R. ECK P. BARKER REMARKS: OPEN HOLE 3-09/L-28A 500292178001 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 17 -APR- 95 RUN 2 RUN 3 8 liN 17E 2750 838 56.00 .00 14.50 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.625 10540.0 8.500 14700.0 DIFL/CN/ZDL/GR. CIRCULATION STOPPED @ 20:30, 23-MAR-95. TOOL STRING WAS DRILLPIPE CONVEYED. PER CLIENT'S REQUEST, THE REFERENCE CURVE FOR THIS WELL IS THE GR FROM THE SBT LOG DATED 13-APR-95. TOOL STRING WAS MOMENTARILY STUCK ON BOTTOM PRIOR TO STARTING MAIN PASS. HAD TO WORK DRILLPIPE BACK DOWN HOLE FOR REPEAT PASS. CALIPER, PE, & ZCOR ON REPEAT PASS INDICATE INCREASED BUILDUP ON TOOL. AFTER LOG VERIFICATION OF CALIPER NOT AVAILABLE DUE TO PCL OPERATIONS. PER CLIENT'S REQUEST, BOREHOLE & TORNADO CHART CORREC- TIONS WERE APPLIED TO THE DIL DATA. THE DIL DATA WAS CORRECTED FOR BOREHOLE SIZE (8.500"). THE CORRECTED DATA WAS THEN USED IN THE ATLAS TORNADO CHART TO GET "RT" & "DI" CURVES. RT = TRUE FORMATION RESISTIVITY. DI = DEPTH OF INVASION. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, CALIPER CORRECTED, CASING CORRECTIONS OFF, CHISM FILTERING IS ACTIVE, SALINITY = 0.00 PPM. FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS Ail tool strings; hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR DIL SDN 2435 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA depth shifted and clipped curves; .5000 START DEPTH STOP DEPTH 13778.0 14537.0 13843.0 14602.0 13807.0 14561.0 13785.0 14543.0 GRCH from SBT dated 13-APR-95. (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GR 13788.0 13791.0 13804.0 13807.5 13840.0 13844.5 13851.0 13851.5 13861.0 13881.5 13884.5 13893.0 13893.5 13925.0 13925.5 13926.0 13942.0 13942.5 13949.0 13961.5 13965.5 13966.0 13966.5 13970.0 13970.5 13976.5 13982.0 14002.0 14002.5 14006.5 14016.0 14026.0 14030.0 14048.5 14060.5 14061.0 14063.5 14064.0 14068.0 14069.5 14082.5 14094.5 14109.5 LL8 13844.5 ILD NPHI RHOB 13854.0 13865.5 13865.5 13865.5 13885.0 13888.5 13896.5 13896.5 13896.5 13897.0 all runs merged; 13857.5 13865.5 13885.0 13888.5 13896.5 13928.5 13928.5 13928.5 13947.5 13930.0 13929.5 13946.5 13945.5 13953.5 13952.0 13953.5 13965.0 13965.0 13965.0 13969.5 13970.0 13969.5 13969.0 13974.0 13974.0 13975.0 13974.0 13979.5 14006.0 14006.0 14005.5 14006.0 14010.5 14019.5 14019.5 14019.5 14064.5 14065.5 14029.0 14032.5 14052.5 14065.0 14068.5 14085.0 14097.5 14064.0 14073.5 14068.0 14072.5 14098.0 14113.0 13947.5 13953.5 13965.0 13969.0 13986.0 14006.0 14019.0 14064.5 14073.5 no case 14110. 14113. 14129. 14141. 14153. 14153. 14162. 14164. 14166. 14166. 14172. 14184. 14184. 14189. 14190. 14208. 14209. 14218. 14219. 14239. 14239. 14246. 14253. 14260. 14261. 14266. 14266. 14268. 14268. 14271. 14275. 14278. 14280. 14280. 14288. 14297. 14297. 14299. 14300. 14301. 14301. 14304. 14326. 14331. 14341. 14346. 14346. 14347. 14360. 14372. 14377. 14377. 14379. 14384. 14384. 14389. 14401. 14405. 14406. 14427. 14157.0 14165.5 14170.5 14188.0 14193.5 14213.0 14222.0 14243.0 14270.5 14273.0 14275.0 14279.5 14282.0 14284.0 14301.0 14304.0 14306.0 14335.5 14350.5 14376.5 14382.5 14389.5 14410.0 14432.5 14158.0 14164.5 14166.0 14168.5 14189.0 14194.0 14213.0 14222.0 14241.5 14270.5 14273.0 14275.0 14279.5 14282.0 14284.0 14301.0 14304.0 14306.0 14335.5 14351.0 14377.0 14382.5 14389.5 14410.0 14432.5 14112.0 14116.0 14133.0 14142.0 14156.0 14168.5 14175.5 14192.5 14211.0 14221.0 14248.0 14265.0 14278.5 14290.5 14302.5 14309.0 14331.0 14351.5 14385.5 14392.5 14406.0 14156.5 14165.5 14170.5 14188.0 14193.5 14213.0 14222.0 14243.0 14263.5 14268.5 14273.0 14275.0 14279.5 14282.0 14284.0 14301.0 14304.0 14305.5 14335.5 14345.0 14350.5 14364.0 14376.5 14382.5 14389.5 14410.0 14432.5 14156.0 14165.5 14170.0 14188.0 14193.0 14213.0 14222.0 14242.5 14256.5 14263.5 14269.0 14271.5 14275.0 14279.5 14284.0 14300.5 14303.0 14305.0 14335.5 14345.0 14350.5 14364.0 14381.5 14388.5 14410.0 14432.5 14428.5 14430.5 14431.0 14461.0 14464.0 14464.5 14469.5 14478.5 14483.5 14489.5 14492.0 14503.0 14506.0 14507.0 14508.5 14516.5 14521.5 14524.5 14525.0 14528.5 14529.0 14531.5 14535.5 14544.0 14556.5 14571.5 14582.0 $ MERGED DATA SOURCE PBU TOOL CODE GR DIL SDN 2435 $ REMARKS: 14434.0 14436.5 14469.5 14474.5 14487.5 14434.0 14436.5 14469.5 14474.5 14483.5 14487.5 14509.0 14436.0 14464.5 14493.5 14434.0 14436.5 14469.0 14474.5 14487.5 14517.5 14523.5 14530.5 14534.0 14512.0 14519.0 14526.5 14532.0 14540.5 14546.5 14557.0 14577.5 14583.5 14530.5 14535.0 RUN NO. PASS NO. MERGE TOP 1 4 13778.0 1 4 13843.0 1 4 13807.0 1 4 13785.0 MAIN PASS. MTEM, TEND, & TENS WERE SHIFTED WITH LL8. ILM, SP, RT, & DI WERE SHIFTED WITH ILD. FUCT & NUCT WERE SHIFTED WITH NPHI. DRHO, PEF, & CALl WERE SHIFTED WITH RHOB. 14433.5 14435.5 14469.5 14474.5 14487.5 14495.5 14511.0 14513.0 14526.0 14530.5 14535.0 MERGE BASE 14537.0 14602.0 14561.0 14543.0 /??MATCH1.OUT /??MATCH2.OUT /??MATCH3.OUT /??MATCH4.OUT /??MATCH5.OUT $ CN : BP EXPLORATION WN : 3-09/L-28A FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME (ALASKA) Tape depth ID: F 17 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR DIL 68 1 GAPI 2 LL8 DIL 68 1 OHMM 3 ILM DIL 68 1 OHMM 4 ILD DIL 68 1 OHMM 5 RT DIL 68 1 OHMM 6 DI DIL 68 1 IN 7 SP DIL 68 1 MV 8 MTEM DIL 68 1 DEGF 9 TEND DIL 68 1 LB 10 TENS DIL 68 1 LB 11 RHOB SDN 68 1 G/C3 12 DRHO SDN 68 1 G/C3 13 PEF SDN 68 1 BN/E 14 CALl SDN 68 1 IN 15 NPHI 2435 68 1 PU-S 16 FUCT 2435 68 1 CPS 17 NUCT 2435 68 1 CPS 4 4 50 746 76 1 4 4 50 746 76 1 4 4 50 746 76 1 4 4 50 746 76 1 4 4 50 746 76 1 4 4 50 746 76 1 4 4 50 746 76 1 4 4 50 746 76 1 4 4 50 746 76 1 4 4 50 746 76 1 4 4 22 779 91 0 4 4 22 779 91 0 4 4 22 779 91 0 4 4 22 779 91 0 4 4 98 211 23 1 4 4 98 211 23 1 4 4 98 211 23 1 68 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 122 Tape File Start Depth = 14618.000000 Tape File End Depth = 13770.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 30547 datums Tape Subfile: 2 364 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 2 RAW OPEN HOLE MAIN PASS Composite of all curves and log header data from all tool strings for a single run; Run #1 presented first followed by separate files for any other subsequent runs. RUN NUMBER: 1 1 4 .2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 13775.0 14540.0 DIFL 13837.0 14606.0 ZDL 13802.0 14564.0 2435 13783.5 14546.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): 24-MAR-95 FSYS REV. J001 VER. 1.1 2030 23-MAR-95 256 25-MAR-95 14700.0 14608.0 13777.0 14606.0 900.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV CHT MIS MODL KNJT GR CN ZDL KNJT KNJT RB TEMP PCM DIFL $ SWIVEL SUB CABLEHEAD TENSION MASS ISOLATION SUB MODAL SUB KNUCKLE JOINT GAMMA RAY COMPENSATED NEUTRON Z-DENSITY KNUCKLE JOINT KNUCKLE JOINT RB SUB TEMPERATURE PULSE CODE MODULATOR DUAL INDUCTION TOOL NUMBER 3944XA 3974XA 3967XA 3517NA 3921NA 1309XA 2435XA 2222EA/2222MA 3921NA 3921NA 3975XA 2806XA 3506XA 1503XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 8.500 10540.0 .0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): KCL/POLYMER 10.50 74.0 MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 3-09/L-28A : ENDICOTT : NORTH SLOPE : ALASKA 9.7 5.0 200.0 .872 .279 .772 .000 1.260 .000 THERMAL SANDSTONE 2.65 .000 1.5 64.0 200.0 64.0 .0 65.0 .0 * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 21 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 GR DIFL 68 1 GAPI RFOC DIFL 68 1 OHMM RILM DIFL 68 1 OHMM RILD DIFL 68 1 OHMM VILD DIFL 68 1 MV RT DIFL 68 1 OHMM DI DIFL 68 1 IN SP DIFL 68 1 MV TEMP DIFL 68 1 DEGF CHT DIFL 68 1 LB TTEN DIFL 68 1 LB SPD DIFL 68 1 F/MN ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 PE ZDL 68 1 BN/E CAL ZDL 68 1 IN CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S CN 2435 68 1 PU-L LSN 2435 68 1 CPS 4 4 67 456 14 5 4 4 27 515 24 6 4 4 06 213 78 0 4 4 04 903 06 0 4 4 04 522 10 6 4 4 04 903 06 0 4 4 06 213 78 0 4 4 53 419 67 0 4 4 40 467 34 0 4 4 78 867 34 0 4 4 78 867 34 0 4 4 13 331 34 0 4 4 52 443 33 1 4 4 09 884 61 1 4 4 76 731 33 1 4 4 24 115 90 6 4 4 98 211 23 1 4 4 98 211 23 1 4 4 52 326 75 5 4 4 84 023 70 1 21 SSN 2435 68 1 CPS 4 4 83 368 34 1 * DATA RECORD (TYPE# 0) Total Data Records: 309 974 BYTES * 84 Tape File Start Depth = 14618.000000 Tape File End Depth = 13770.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 74647 datums Tape Subfile: 3 393 records... Minimum record length: 62 bytes Maximum record length: 974 bytes Tape Subfile 4 is type: LIS RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 5 .2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 13968.5 14346.0 DIFL 14029.0 14412.0 ZDL 13993.0 14366.0 2435 13974.0 14352.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV CHT MIS MODL KNJT GR CN ZDL KNJT KNJT RB TEMP PCM DIFL $ SWIVEL SUB CABLEHEAD TENSION MASS ISOLATION SUB MODAL SUB KNUCKLE JOINT GAMMA RAY COMPENSATED NEUTRON Z-DENSITY KNUCKLE JOINT KNUCKLE JOINT RB SUB TEMPERATURE PULSE CODE MODULATOR DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: 24-MAR-95 FSYS REV. J001 VER. 1.1 2030 23-MAR-95 553 25-MAR-95 14700.0 14608.0 13777.0 14606.0 900.0 TOOL NUMBER 3944XA 3974XA 3967XA 3517NA 3921NA 1309XA 2435XA 2222EA/2222MA 3921NA 3921NA 3975XA 2806XA 3506XA 1503XA 8.500 10540.0 .0 KCL/POLYMER 10.50 74.0 9.7 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: REPEAT PASS. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 3-09/L-28A ·· ENDICOTT : NORTH SLOPE : ALASKA 5.0 200.0 .872 .279 .772 .000 1.260 .000 THERMAL SANDSTONE 2.65 .000 1.5 64.0 200.0 64.0 .0 65.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 21 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 GR DIFL 68 1 GAPI RFOC DIFL 68 1 OHMM RILM DIFL 68 1 OHMM RILD DIFL 68 1 OHMM VILD DIFL 68 1 MV RT DIFL 68 1 OHMM DI DIFL 68 1 IN SP DIFL 68 1 MV TEMP DIFL 68 1 DEGF CHT DIFL 68 1 LB TTEN DIFL 68 1 LB SPD DIFL 68 1 F/MN ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 PE ZDL 68 1 BN/E CAL ZDL 68 1 IN CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S CN 2435 68 1 PU-L LSN 2435 68 1 CPS SSN 2435 68 1 CPS 4 4 67 456 14 5 4 4 27 515 24 6 4 4 06 213 78 0 4 4 04 903 06 0 4 4 04 522 10 6 4 4 04 903 06 0 4 4 06 213 78 0 4 4 53 419 67 0 4 4 40 467 34 0 4 4 78 867 34 0 4 4 78 867 34 0 4 4 13 331 34 0 4 4 52 443 33 1 4 4 09 884 61 1 4 4 76 731 33 1 4 4 24 115 90 6 4 4 98 211 23 1 4 4 98 211 23 1 4 4 52 326 75 5 4 4 84 023 70 1 4 4 83 368 34 1 * DATA RECORD (TYPE# 0) Total Data Records: 166 974 BYTES * Tape File Start Depth = 14424.000000 Tape File End Depth = 13968.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 70698 datums Tape Subfile: 4 249 records... Minimum record length: 62 bytes Maximum record length: 974 bytes 84 Tape Subfile 5 is type: LIS 95/ 4/17 01 **** REEL TRAILER **** 95/ 4/18 01 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 18 APR 95 11:35a Elapsed execution time = 9.33 seconds. SYSTEM RETURN CODE = 0 C Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 3 -09 / L- 28A 500292178001 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 07-MAR-96 6397.12 D. BARBA J. POWERS 8 11N 17E 2530 838 0.00 56.0O 14.50 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 9.625 14186.0 3RD STRING 7.000 12638.0 PRODUCTION STRING 4.500 12393.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS SBT GRCH 1 1 06-MAY-95 WALS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: 47.00 26.00 12.60 BASELINE DEPTH 13896.0 13902.0 13908.0 13909.5 13910.5 13923.0 13924.5 13932.0 13932.5 13933.5 13934.0 13937.0 13938.0 ......... EQUIVALENT UNSHIFTED DEPTH ......... GRCH 13899.5 13905.5 13911.5 13913.5 13914.5 13926.0 13927.5 13935.0 13936.5 13937.5 13938.5 13941.5 13942.0 14218.0 14225.5 14237.0 14243.0 14253.5 14256.0 14257.0 14258.0 14260.0 14266.0 14266.5 14268.0 14271.0 14275.0 14277.0 14278.0 14287.5 14288.0 14289.0 14290.0 14299.5 14301.0 14305.5 1437~2.5 ~2~3.0 14346.5 14350.0 14371.5 14374.0 14378.5 14379.0 14379.5 14380.5 14384.0 14392.0 14393.0 14393.5 14405.5 14416.0 14426.5 14428.5 14430.5 14460.0 14464.5 14469.5 14474.5 14476.5 14479.5 14480.5 14483.0 14483.5 $ REMARKS: 14221.5 14229.0 14240.5 14246.5 14257.5 14260.0 14261.0 14261.5 14263.5 14269.5 14270.5 14272.5 14275.0 14278.5 14281.0 14281.5 14291.0 14292.0 14293.0 14293.5 14303.0 14305.0 14309.0 14317.0 14317.5 14346.5 14350.0 14374.0 14377.0 14381.5 14382.5 14383.0 14383.5 14387.0 14395.0 14395.5 14396.0 14407.0 14419.0 14429.5 14431.5 14434.0 14463.5 14467.5 14472.5 14478.0 14480.0 14483.0 14483.5 14486.0 14486.5 CN/GR Cased Hole. TIED INTO SBT DATED 06-MAY-95. PUMPED 200 BBLS SEAWATER TO GET THE TOOL THRU TUBING. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, CHISM OFF, CALIPER & CASING CORRECTED, SALINITY = 0.0 PPM. SHIFT PROCEDURE AS FOLLOWS: 1) FIRST PASS GAMMA RAY DEPTH MATCHED TO SBT GAMMA RAY, LOGGED 06-MAY-95. 2) FIRST PASS NEUTRON DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 3) ALL SUBSEQUENT GAMMA RAY PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 4) ALL SUBSEQUENT NEUTRON PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS NEUTRON. / ? ?MATCHIA. OUT $ FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each run PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH 2418 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH 13891.0 13900.0 STOP DEPTH 14509.0 14518.0 (MEASURED DEPTH) BASELINE DEPTH 13902.0 13924.5 13946.0 13965.0 13970.0 13979.0 13980.0 13981.0 13982.0 13982.5 13987.5 13989.0 14001.5 14012.0 14013.5 14015.5 14023.5 14024.5 14055.5 14056.0 14057.0 14061.0 14070.0 14088.5 14092.0 14093.0 14150.5 14151.5 14153.5 14161.5 14163.5 14166.0 14169.0 14169.5 14170.0 14171.0 14173.0 14173.5 14175.0 in separate files. ......... EQUIVALENT UNSHIFTED DEPTH ......... NPHI 13904.5 13926.5 13946.5 13969.0 13974.0 13983.0 13983.5 13984.0 13985.0 13986.0 13991.0 13993.0 14006.0 14016.0 14017.0 14019.0 14027.0 14027.5 14057.5 14058.0 14058.5 14065.5 14074.0 14093.5 14097.0 14097.5 14155.0 14155.5 14157.0 14165.5 14167.0 14169.5 14172.5 14173.5 14174.0 14174.5 14176.5 14177.5 14179.0 14176.5 14179.5 14180.0 14181.0 14182.0 14184.0 14189.5 14194.0 14195.0 14197.0 14197.5 14198.5 14204.0 14209.0 14212.5 14213.5 14214.0 14218.0 14225.5 14237.0 14243.0 14253.5 14256.0 i42~7.0 14258.0 14261.0 14268.0 14275.0 14287.5 14288.0 14289.0 14290.0 14296.0 14299.5 14301.0 14305.5 14346.5 14350.0 14371.5 14378.5 14379.0 14379.5 14380.5 14384.0 14392.0 14393.0 14393.5 14400.5 14405.5 14416.0 14426.5 14428.5 14430.5 14460.0 14468.0 14474.5 14479.5 14480.5 14483.0 14483.5 14179.5 14183.0 14183.5 14184.0 14184.5 14188.0 14193.0 14198.0 14198.5 14200.5 14201.5 14202.5 14208.5 14213.0 14217.0 14217.5 14218.0 14222.0 14229.0 14240.5 14246.5 14257.5 14260.0 14261.0 14261.5 14263.0 14270.5 14279.0 14291.0 14292.0 14293.0 14293.5 14300.0 14303.0 14305.0 14309.0 14346.5 14350.0 14375.0 14381.5 14382.5 14383.0 14383.5 14387.5 14395.0 14395.5 14396,0 14401.0 14407.0 14419.0 14429.5 14431.5 14434.0 14463.5 14471.5 14478.5 14483.0 14483.5 14486.0 14486.5 14489.0 $ REMARKS: 14491.5 PASS 1. FUCT & NUCT WERE SHIFTED WITH NPHI. GRCH WAS DEPTH MATCHED TO SBT GAMMA RAY, LOGGED 06-MAY-95. CN WN FN COUN STAT / ??MATCHIB. OUT $ BP EXPLORATION (ALASKA) 3 - 09 / L- 28A ENDICOTT NORTH SLOPE ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod i GRCH 2418 68 i GAPI 4 2 NPHI 2418 68 i PU-S 4 3 FUCT 2418 68 i CPS 4 4 NUCT 2418 68 i CPS 4 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 28 Tape File Start Depth = 14560.000000 Tape File End Depth = 13870.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 6906 datums Tape Subfile: 2 356 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH GRCH 13891.0 2418 13900.0 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: i BASELINE DEPTH 13886.0 13895.5 13896.0 13898.5 13899.0 13901.0 13905.5 13906.0 13908.0 13912.0 13912.5 13917.5 13918.0 13919.0 13923.5 13924.5 13926.0 13927.5 13929.5 13932.0 13940.5 13941.0 13941.5 13942.5 13946.0 13956.0 13962.0 13965.5 13970.0 13973.0 13973.5 13977.0 13978.0 13979.0 13980.0 13986.5 13991.5 for each run in separate files. STOP DEPTH 14509.0 14518.0 (MEASURED DEPTH) ......... EQUIVALENT UNSHIFTED DEPTH ......... GRCH 13889.5 13899.0 13900.0 13902.5 13903.5 13905.5 13911.5 13915.5 13916.0 13926.0 13927.5 13932.0 13935.5 13944.0 13945.0 13947.5 13948.5 13960.0 13982.0 13982.5 13983.5 13990.5 13995.5 NPHI 13898.5 13908.0 13909.5 13921.5 13922.0 13922.5 13930.5 13932.0 13946.5 13963.5 13968.5 13974.0 13976.5 13977.5 13981.0 13981.5 13982.5 13983.0 S ' 966C'i: S ' S66C'i: 14218.0 14226.5 14243.0 14245.5 14246.5 14249.5 14254.5 14255.0 14256.5 14257.5 14261.0 14266.5 14270.5 14271.5 14275.0 14282.5 14283.0 14283.5 14292.0 14296.0 14299.0 14299.5 14.~01.0 i~?01.5 14302.0 14306.5 14307.5 14308.0 14309.0 14310.0 14316.0 14317.0 14318.5 14319.0 14320.0 14320.5 14321.5 14328.0 14328.5 14334.5 14335.5 14336.5 14338.0 14339.0 14340.0 14342.0 14346.5 14349.5 14366.0 14367.0 14368.5 14370.0 14371.5 14376.5 14377.5 14378.0 14379.5 14380.0 14380.5 14381.0 14230.0 14248.5 14251.0 14251.5 14254.0 14259.0 14260.0 14261.5 14262.0 14275.0 14275.5 14286.5 14287.0 14287.5 14303.0 14304.0 14305.5 14311.0 14313.5 14314.5 14315.0 14321.0 14321.5 14323.0 14324.0 14325.0 14326.5 14327.0 14334.0 14335.0 14341.0 14341.5 14342.0 14344.5 14345.0 14351.0 14371.0 14371.5 14381.0 14381.5 14382.5 14384.0 14384.5 14385.5 14222.0 14261.0 14265.5 14269.0 14279.0 14296.0 14301.5 14306.5 14307.5 14313.0 14335.5 14338.5 14342.5 14352.0 14374.0 14375.0 14376.5 14385.0 14385.5 14383.0 14384.0 14385.5 14414.5 14417.0 14425.0 14426.0 14427.0 14429.5 14430.5 14432.5 14436.0 14437.0 14437.5 14438.0 14439.5 14456.5 14457.0 14457.5 14458.5 14459.0 14462.0 14463.5 14464.5 14465.0 14466.5 14467.5 14468.0 14471.0 14472.0 14472.5 14474.5 14477.0 14478.0 14479.0 14480.0 14480.5 14481.5 14484.0 14490.0 14491.0 14495.5 14504.5 14505.0 14507.0 14510.5 14514.0 14515.0 14515.5 14516.5 $ REMARKS: 14387.5 14388.0 14388.0 14390.5 14419.0 14421.5 14430.0 14427.0 14431.0 14429.0 14432.0 14435.5 14435.5 14439.0 14439.5 14442.0 14443.0 14444.5 14461.0 14463.0 14463.5 14464.0 14464.5 14465.0 14466.5 14469.0 14470.0 14472.0 14473.0 14474.0 14473.5 14477.0 14477.5 14477.0 14478.0 14479.0 14481.5 14482.0 14482.5 14483.5 14485.0 14485.5 14490.0 14488.0 14496.0 14497.0 14500.5 14508.0 14509.5 14511.5 14515.0 14517.5 14518.0 14518.5 14519.0 PASS 2. FUCT & NUCT WERE SHIFTED WITH NPHI. / ??MATCH2A. OUT /??MATCH2B. OUT $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 3 - 09 / L- 28A : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPES 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod I GRCH 2418 68 i GAPI 2 NPHI 2418 68 i PU-S 3 FUCT 2418 68 i CPS 4 NUCT 2418 68 1 CPS 4 4 42 995 99 1 4 4 42 995 99 1 4 4 42 995 99 1 4 4 42 995 99 1 16 * DATA RECORD (TYPES 0) 1006 BYTES * Total Data Records: 28 Tape File Start Depth = 14560.000000 Tape File End Depth = 13870.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 6906 datums Tape Subfile: 3 269 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH 2418 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: i START DEPTH 13891.0 13900.0 STOP DEPTH 14509.0 14518.0 (MEASURED DEPTH) ......... EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GRCH 13886.0 13889.5 13895.5 13899.0 13896.0 13900.5 13902.0 ~3905.5 13913.0 13924.5 13928.0 13932.5 13929.0 13933.0 13934.5 13938.5 13935.0 13940.0 13936.5 13941.5 13938.5 13939.0 13943.5 13939.5 13944.0 13940.0 13945.0 13945.0 13950.0 13946.0 13950.5 13953.5 13956.5 13961.0 13957.5 13961.5 13958.0 13962.5 13959.0 13960.0 13961.0 13961.5 13966.0 13962.5 13967.5 13964.0 13969.0 13964.5 13970.0 13965.5 13971.0 13966.5 13971.5 13969.5 13974.5 13970.0 13975.5 13976.0 13979.0 13979.5 13985.0 13980.0 NPHI 13898.5 13906.5 13908.0 13917.5 13928.0 13934.0 13942.0 13948.0 13957.0 13963.0 13963.5 13964.0 13965.5 13970.5 13976.0 13982.0 13985.0 13985.5 13980.5 13982.5 13983.0 13983.5 13987.0 13997.0 14000.0 14005.5 14010.0 14011.0 14013.5 14014.5 14018.0 14019.5 14020.5 14022.0 14022.5 14023.0 14024.5 14025.5 14026.0 14052.5 14056.5 14057.5 14058.0 14058.5 14059.0 14059.5 14060.0 14061.0 14068.0 14068.5 14070.0 14075.5 14076.0 14077.5 14081.5 14082.0 14083.0 14086.5 14149.5 14150.0 14151.5 14152.0 14153.0 14154.0 14154.5 14163.5 14168.0 14168.5 14169.5 14170.0 14170.5 14171.0 14171.5 14172.5 14174.5 14175.5 14176.0 14182.5 13985.5 13987.0 13987.5 13991.0 14005.5 14015.5 14016.0 14024.5 14028.5 14029.0 14029.5 14060.5 14062.0 14063.0 14063.5 14064.0 14074.0 14155.0 14155.5 14156.0 14156.5 14157.0 14158.0 14159.0 14174.0 14174.5 14175.5 14176.0 14178.0 14178.5 14179.0 14186.0 13987.5 14002.0 14010.0 14018.0 14018.5 14022.0 14024.0 14025.5 14026.5 14027.0 14055.5 14062.5 14063.5 14064.0 14064.5 14065.0 14072.0 14073.0 14080.0 14081.0 14082.5 14085.5 14086.0 14086.5 14090.0 14167.5 14172.0 14173.0 14174.5 14175.0 0'6£E9I 0 '9LEgI ~ '0£~9I 0'89E9I g 'L9EgI 0 '99E~I 0 O'~9E~I O'08E~I ~'gtZgI g'99E~I 0'09~9I 0'89~9I 0'60Z9I 0 '80Z9I ~'~OZgI 0'8619I 0'£619I g'9619I O'LSIgI 14276.5 14277.0 14282.0 14284.0 14287.5 14288.0 14288.5 14289.0 1429O.5 14291.5 14292.0 14292.5 14293.5 14294.5 14296.0 14296.5 14297.0 14301.0 14303.0 14303.5 !47-34.5 .-. ~. i 36.0 i~ ._.77.0 14307.5 14308.0 14319.0 143 !9.5 14320.0 14322.0 14322.5 14325.5 14326.5 14327.0 14332.5 14333.5 14334.5 14335.5 14346.5 14349.0 14367.5 14368.5 14369.5 14370.5 14371.0 14371.5 14374.5 14375.5 14376.5 14378.0 14379.0 14379.5 14380.5 14381.5 14382.0 14383.0 14384.0 14388.5 14390.5 14391.0 14392.0 14280.5 14281.0 14291.5 14292.5 14295.0 14295.5 14296.5 14298.0 14298.5 14300.5 14301.5 14311.5 14313.0 14324.0 14325.0 14325.5 14326.0 14327.0 14330.5 14331.5 14332.5 14338.0 14339.5 14340.5 14341.0 14346.5 14373.0 14373.5 14374.0 14374.5 14375.0 14376.5 14379.0 14380.0 14381.5 14383.0 14383.5 14384.0 14384.5 14385.0 14386.0 14388.0 14288.0 14290.0 14292.0 14292.5 14293.5 14298.0 14298.5 14299.0 14300.0 14305.5 14307.0 14307.5 14308.0 14308.5 14309.0 14350.5 14373.0 14376.0 14384.5 14387.0 14388.5 14392.5 14394.5 14395.5 14396.5 c~ ' 9 ~:cj~'l: 0 ' 9 ~:cj~'i: 0 'OL~I g ' 69~I 0 '89~I 0'99~I g'~O~I g'66~ g'86£~I 0'86~I S'L6~I 0 O'L6~I g'999~I 0'L6~9I 14541.0 14541.5 14542.0 14551.0 14551.5 REMARKS: 14546.0 14546.5 14547.0 14556.0 14556.5 PASS 3. FUCT & NUCT WERE SHIFTED WITH NPHI. CN WN FN COUN STAT / ??MATCH3A. OUT / ??MATCH3B. OUT $ : BP EXPLORATION (ALASKA) : 3 - 09 / L- 28A : ENDICOTT : NORTH SLOPE : ALASKA ~. FOPd~AT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod I GRCH 2418 68 I GAPI 4 2 NPHI 2418 68 i PU-S 4 3 FUCT 2418 68 I CPS 4 4 NUCT 2418 68 1 CPS 4 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 28 Tape File Start Depth = 14560.000000 Tape File End Depth = 13870.000000 Tape File Level Spacing = 0.500000 Tape File Depth Unit~ = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 13812 datums Tape Subfile: 4 344 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH 2418 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH 13891.0 13900.0 BASELINE DEPTH 13896.0 13900.0 ~.3904.5 13905.5 13906.0 13908.0 13909.0 13910.5 13911.5 13915.0 13917.0 13923.5 13924.5 13926.0 13927.0 13927.5 13928.5 13929.0 13931.5 13932.0 13933.0 13934.0 13935.0 13938.5 13946.0 13951.5 13955.5 13958.0 13958.5 13959.5 13962.5 13964.5 13965.0 13965.5 13969.0 13969.5 13977.0 STOP DEPTH 14509.0 14518.0 (MEASURED DEPTH) ......... EQUIVALENT UNSHIFTED DEPTH ......... GRCH NPHI 13900.5 13898.5 13902.5 13907.5 13908.0 13909.0 13911.5 13911.0 13911.5 13913.0 13913.5 13918.0 13920.0 13926.0 13927.0 13928.5 13929.0 13929.5 13930.0 13930.5 13934.0 13935.5 13936.5 13937.0 13939.0 13939.5 13948.5 13948.5 13955.5 13960.0 13962.5 13963.0 13964.0 13966.5 13968.5 13969.5 13970.0 13972.0 13972.5 13982.0 13978.0 13979.0 13980.5 14001.5 14015.5 14024.0 14056.0 14058.0 14058.5 14060.0 14060.5 14062.5 14063.5 14068.0 14068.5 14070.0 14076.0 14150.5 14151.0 14152.0 14153.0 14154.0 14160.0 14171.5 14174.0 14175.0 14183.5 14184.0 14187.0 14191.5 14194.5 14195.5 14196.5 14197.5 14199.0 14205.0 14206.0 14207.0 14208.5 14209.0 14210.0 14218.0 14220.5 14221.5 14225.0 14225.5 14226.5 14245.5 14246.5 14247.5 14251.5 14252.0 14252.5 14253.5 14255.0 14256.0 14256.5 14260.5 14261.0 14261.5 13982.5 13983.0 14005.5 14019.5 14028.0 14061.0 14063.5 14064.0 14074.0 14155.0 14155.5 14156.0 14157.0 14157.5 14163.5 14175.5 14178.0 14178.5 14187.0 14188.0 14191.0 14196.0 14199.0 14199.5 14203.0 14209.5 14210.5 14211.0 14212.5 14213.5 14222.5 14225.0 14225.5 14229.5 14250.5 14258.0 14260.0 14260.5 14265.0 14265.5 13985.5 14062.0 14063.5 14065.5 14066.0 14070.5 14071.5 14079.0 14200.5 14201.5 14214.5 14229.5 14230.5 14231.5 14250.0 14250.5 14254.5 14255.5 14256.0 14261.5 14264.5 14263.0 14266.5 14268.0 14269.0 14270.0 14270.5 14271.0 14272.5 14273.0 14273.5 14274.0 14274.5 14275.0 14276.0 14277.0 14283.5 14285.0 14286.5 14287.0 14287.5 14289.0 14289.5 14290.5 14292.0 14294.5 14295.5 14296.5 14299.5 14300.5 14301.0 14305.5 14306.5 14308.0 14309.0 14310.0 14310.5 14320.5 14321.0 14327.0 14328.0 14328.5 14329.0 14330.5 14331.0 14333.0 14334.0 14334.5 14335:0 14336.0 14340.0 14349.0 14349.5 14355.0 14366.5 14368.0 14369.0 14369.5 14370.0 14371.5 14380.5 14270.5 14272.5 14275.5 14278.5 14279.5 14280.5 14281.0 14290.5 14291.5 14292.5 14294.5 14295.0 14299.0 14299.5 14305.5 14310.5 14312.5 14313.5 14314.0 14315.0 14325.0 14326.0 14329.5 14330.5 14331.5 14332.0 14333.5 14336.5 14338.5 14339.0 14340.0 14340.5 14349.5 14370.0 14372.5 14374.0 14267.0 14269.5 14272.0 14272.5 14273.0 14273.5 14276.0 14276.5 14277.5 14278.5 14288.0 14288.5 14293.0 14293.5 14297.0 14300.0 14304.5 14305.0 14310.0 14310.5 14313.0 14334.5 14340.0 14349.5 14360.5 14372.0 14373.5 14374.0 14375.5 14384.5 14382.0 14382.5 14384.0 14386.5 14393.0 14394.5 14395.0 14415.5 14416.0 14426.5 14430.5 14432 · 5 14435.5 14436.5 14437.0 14437.5 14438.0 14456.5 14457.5 14459.5 14460.5 14462.0 1~63.0 1~? 464.0 1~ 465.0 1.~ ~71.5 14472.5 14473.5 14477.5 14480.5 14481.5 14482.5 14484.0 14486.5 14487.5 14488.5 14489.5 14490.0 14490.5 14491.0 14491.5 14492.0 14496.0 14500.5 14502.0 14502.5 14503.0 14504.0 14504.5 14505.0 14506.0 14508.5 14509.0 14510.0 14512.0 14513.5 14514.0 $ REMARKS: PASS 14386.0 14387.0 14391.5 14432.0 14436.0 14442.5 14443.5 14462.0 14462.5 14464.5 14465.0 14466.5 14467.0 14470.0 14478.5 14481.5 14483.5 14487.0 14493.0 14495.5 14506.5 14507.5 14508.0 14517.0 14517.5 . 14386.5 14389.0 14397.5 14398.0 14398.5 14421.5 14422.0 14438.0 14441.0 14441.5 14442.5 14468.5 14469.0 14476.5 14477.0 14486.0 14486.5 14492.5 14493.5 14494.0 14495.5 14496.0 14497.0 14497.5 14498.0 14501.5 14506.5 14508.0 14509.5 14510.0 14510.5 14513.0 14513.5 14514.5 14516.5 14517.0 FUCT & NUCT WERE SHIFTED WITH NPHI. CN WN FN COUN STAT / ? ?MATCH4A. OUT /??MATCH4B. OUT $ : BP EXPLORATION (ALASKA) : 3 - 09 / L - 28A : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPES 64 ) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod i GRCH 2418 68 i GAPI 4 2 NPHI 2418 68 i PU-S 4 3 FUCT 2418 68 I CPS 4 4 NUCT 2418 68 i CPS 4 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 28 Tape File Start Depth = 14560.000000 Tape File End Depth = 13870.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 13812 datums Tape Subfile: 5 276 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass i gamma ray and background counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT: 0.5000 PASSES INCLUDED IN AVERAGE PBU TOOL CODE PASS NUMB~S GRCH 2418 $ REMARKS: CN WN FN COUN STAT 1, ~2, 3, 4 1, 2, 3, 4 AVERAGED PASS. GRCH, NPHI, FUCT, & NUCT WERE AVERAGED FOR ALL 4 PASSES. $ : BP EXPLORATION (ALASKA) : 3 - 09 / L - 28A : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod i GRCH CNAV 68 1 GAPI 2 NPHI CNAV 68 I PU-S 3 FUCT CNAV 68 1 CPS 4 NUCT CNAV 68 1 CPS 4 4 38 995 99 1 4 4 38 995 99 1 4 4 38 995 99 1 4 4 38 995 99 1 16 * DATA RECORD (TYPES 0) 1006 BYTES * Total Data Records: 28 Tape File Start Depth = 14560.000000 Tape File End Depth = 13870.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 20718 datums Tape Subfile: 6 51 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 13886.0 2418 13895.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SBAR PCM GR CN $ SWIVEL SUB SINKER BAR PCM/CCL GAMMA RAY STOP DEPTH 14537.5 14546.5 COMPENSATED NEUTRON 07-FEB-96 FSYS REV. J001 VER. 1.1 1632 07-FEB-96 14554.0 14520.0 13900.0 14518.0 1200.0 YES TOOL NUMBER 3913NA 8250EA/8248EA 8262XA 2418XA BOREHOLEAND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 14186.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PRODUCED FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 400 NEAR COUNT RATE LOW SCALE (CPS): 50 NEAR COUNT RATE HIGH SCALE (CPS): 1050 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 1. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 3 - 09 / L - 28A · ENDICOTT · : NORTH SLOPE · · ALASKA * FORMAT RECORD (TYPES 64) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod I GR 2418 68 1 GAPI 2 CNC 2418 68 1 PU-S 3 CN 2418 68 1 PU-L 4 LSN 2418 68 1 CPS 5 SSN 2418 68 i CPS 6 CCL 2418 68 1 7 SPD 2418 68 i F/MN 8 TEN 2418 68 i LB 4 4 42 310 01 1 4 4 42 995 99 1 4 4 42 890 01 1 4 4 42 334 31 1 4 4 42 334 30 1 4 4 42 150 01 1 4 4 42 636 99 1 4 4 42 635 99 1 32 * DATA RECORD (TYPES 0) 1014 BYTES * Total Data Records: 97 Tape File Start Depth = 14550.000000 Tape File End Depth = 13878.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 38014 datums Tape Subfile: 7 Minimum record length: Maximum record length: 173 records... 42 bytes 1014 bytes 000 '0 O0 '0 HNO,I,S~N~S 0'0 000 '0 000 '0 000 '0 0'0 0 0'0 0'0 00 '0 S(IlfYI& (]HOfl(IOHd 0'0 0 '98I~I 000 '0 :(~&) HEdHO DNIS~D S,HHODOq :(J~/) HJ~/HG DNIS~O S,HHq~IHG :(NI) HZIS EI~ HqOH NHdO ~O DNIS~O GN-~ HqOHHHO~ ~fXSI~E HH~WI1N qO0~ SMA 0 '00ZI 0 ' 8I~9I 0 ' 006CI 0 0'9g~9I 96-/~H&-L0 IILI I'I 'HHA I00£ 'AHH 96-~H.~-/-0 HA~HG ~OAS HdX~ qOO~ HGOD qO0~ HOGNHA (~O~LO~ OA MO&) DNIHAS ~00~ SIq :adA~ s! 8 ~I!~qns ad~ BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 400 NEAR COUNT RATE LOW SCALE (CPS): 50 NEAR COUNT RATE HIGH SCALE (CPS): 1050 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 2. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 3 - 09 / L- 28A : ENDICOTT : NORTH SLOPE : ALASKA * FOP~M_AT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves-. Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod I GR 2418 68 i GAPI 2 CNC 2418 68 1 PU-S 3 CN 2418 68 1 PU-L 4 LSN 2418 68 1 CPS 5 SSN 2418 68 1 CPS 6 CCL 2418 68 1 7 SPD 2418 68 i F/MN 8 TEN 2418 68 1 LB 4 4 42 310 01 1 4 4 42 995 99 1 4 4 42 890 01 1 4 4 42 334 31 1 4 4 42 334 30 1 4 4 42 150 01 1 4 4 42 636 99 1 4 4 42 635 99 1 32 * DATA RECORD (TYPES 0) 1014 BYTES * Total Data Records: 98 Tape File Start Depth = 14556.000000 Tape File End Depth = 13876.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 45208 datums Tape Subfile: 8 Minimum record length: Maximum record length: 174 records... 62 bytes 1014 bytes Tape Subfile 9 is type: LIS FILE HEADER FILE NUMBER: 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 13883.0 2418 13892.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 14546.5 14555.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL SUB SBAR SINKER BAR PCM PCM/CCL GR GAMMA RAY CN COMPENSATED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 07-FEB-96 FSYS REV. J001 VER. 1.1 1748 07-FEB-96 14554.0 14520.0 13900.0 14518.0 1200.0 YES TOOL NUMBER 3913NA 8250EA/8248EA 8262XA 2418XA 0.000 14186.0 0.0 PRODUCED FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 THERMAL SANDSTONE 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 400 NEAR COUNT RATE LOW SCALE (CPS): 50 NEAR COUNT RATE HIGH SCALE (CPS): 1050 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 3. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 3 - 09 / L - 28A : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPES 64 ) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves-. Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod I GR 2418 68 i GAPI 4 2 CNC 2418 68 I PU-S 4 3 CN 2418 68 i PU-L 4 4 LSN 2418 68 1 CPS 4 5 SSN 2418 68 I CPS 4 6 CCL 2418 68 1 4 7 SPD 2418 68 I F/MN 4 8 TEN 2418 68 i LB 4 4 42 310 01 1 4 42 995 99 1 4 42 890 01 1 4 42 334 31 1 4 42 334 30 1 4 42 150 01 4 42 636 99 1 4 42 635 99 1 32 * DATA RECORD (TYPES 0) 1014 BYTES * Total Data Records: 99 Tape File Start Depth = 14559.000000 Tape File End Depth = 13871.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 62792 datums Tape Subfile: 9 Minimum record length: Maximum record length: 175 records... 62 bytes 1014 bytes Tape Subfile 10 is type: LIS FILE HEADER FILE NUMBER: 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 4 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 13882.0 2418 13891.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SBAR PCM GR CN $ SWIVEL SUB SINKER BAR PCM/CCL GAMMA RAY STOP DEPTH 14540.5 14549.5 COMPENSATED NEUTRON 07-FEB-96 FSYS REV. J001 VER. 1.1 1828 07-FEB-96 14554.0 14520.0 13900.0 14518.0 1200.0 YES TOOL NUMBER 3913NA 8250EA/8248EA 8262XA 2418XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 14186.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PRODUCED FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 0.00 0.000 smn$~p 86969 89 :~poD d~H :Ka~mmns Bu!poo~p spoo uo!~usssadsa SI~ 000000'Z£SgI = q~d~G puH ~I~ ~dw~ 000000'C~I = gsd~G ~a~S ~I~& 86 :spaoosH wSwG 66 ~C9 E~ ~ 66 9C9 E~ 9 IO OgI E~ ~ I0 068 E~ ~ 66 ~66 E9 9 I0 0I£ E~ ~ ~ S~D I 89 8I~E NSS S ~ S~O I 89 8I~E NS~ ~ ~ q-~ I 89 8I~E ND ~ ~ S-~d I 89 8I~ DND E ~ I~D I 89 819~ HO I AaO AaO 6Oq S$~U~ saId=~s apoo IOO~ amen :saA~nO 8 & :OI g~dap sdw~ H~fH~ ~d H .,~_~u HNO (~9 #HdX~) GHODHH ~Fm~HO~ ~ ~fHSk~I%f· ' HdO~S H.T. HON : ,TJ, ODIONH : %fSE -q / 60- Z : (krHS~fT~) NOI,T,~rHO~dXH d~[ : ~AS NnOD N~/ NM ND · 9 SS~f~ : SHHtS~H 0'0 : (Nz) aaooN~ms qooz 0'0 0'0 : (J~/) MOONIM ONIZIq~M'HON HS%fa : (~.~) MOONIM ONIZI~Ikr~r~ON dO3. HNOZ ~IIO NI NOI~fZI~ON H.~,%~H ~N/1OO HNIqHfYI~ Tape Subfile: 10 Minimum recor4 length: Maximum record length-. 174 records... 62 bytes 1014 bytes Tape Subfile 11 is type: LIS 96/ 3/ 4 01 **** REEL TRAILER **** 96/ 3/ 7 01 Tape Subfile: 11 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 7 MAR 96 2:18p Elapsed execution time = 12.69 seconds. SYSTEM RETURN CODE = 0