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Home My WebLink About179-008PLUGGING'& LOCATION- CLEARANCE REPORT State of Alaska · ALASKA OIL & GAS CONSERVATION COMMISSION PTD No. qg-Ooo~ Lease ~Du !~q~$ Memorandum To File: API No. Well Name Operator Location Abnd Date Spud: ,6.;T!~% , TD: 9o5~ , Completed Note casing size, wt, depth, cmt vol, & procedure. Long Csg: ~/~ ~ ~'~°!~'~ %~9o ~/~~s~~o~ Liner: ~ ~ -- ~ Perf intervals - tops Review the well file, and comment on plugging, well head status, and location clearance- provide loc. clear, code. Plugs: .,,a~l $'3 ~0': 5Pol"l.e~ 2.oo' 't~,l~.e~r R,~,o~ I'~'l/~:Sflot. ~ g~S~ ~. A~ lib'. ~ ~(l~5. ~o~ -¢ ~" ~]?~' P~ .~o ~ P~ ~ %00' -~o', ~P ~ ~' ~o~ ~e~ 9o~ o~ 9Z~e: ~o Location :~ear~ce: ~A - oF~~ ~~,o~ Conclusions: .... Code SiDed Unocal Oil & Gas D )n Unocal Corporation RO. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Craig K. White District Exploration Geologist. Alaska District August 1, 1989 Mr. Lonnie C. Smith Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: As requested by the A.O.G.C.C. through A.O.G.A., we 'are providing replacement copies of reproducible (sepia) logs for Unocal-operated wells, as follows: Canoe Bay Unit #1 (Pure Oil Co.) Cannery Loop Unit #1 Cannery Loop Unit #2 Cannery Loop Unlt #3 Clam Gulch Unlt #1 Grayllng 1-A Kasilof Unlt #1 Kenal Unit 41-18 Knlk Arm #1 Knlk Arm St. #1 Kustatan #1 Kustatan #lA Nlnllchik #1 Plttman #1 Pretty Creek Unit #2 (Chevron) Trading Bay Unit G-~O West Trading Bay St. #1 5" E-log 2" E-log 5" BHC, 5" Density~ 5" BHC ~ 5" Density, 2" DIL 2" E-log 2" E-log Mudlog 2" E-log 2" E-log 2" E-log 2" E-log 2" Sonic 5" Microlog 5" CNL, 5" Neutron Ct. Rate GR-Neutron (tie in), CET log 2" & 5" Sonic, 5" Density 2" & 5" BHC, 2" & 5" E-log Please return one copy of this letter in acknowledgement of your receipt of this data. BWS: da 2755E SUMMARY UPPER COOK INLET WEST TRADING BAY WELL #1 CONFIDENTIAL Prepared by: South Alaska Drilling Department ARCO Oil and Gas Company October 31, 1979 TABLE OF CONTENTS Wel 1 Summary ........................... 1 Drilling Rig Time Breakdown.. ,_ ................. 2 Synopsis of Drilling'OPerations .............. 3 Bit Information Bit Cost Table .............. 5 Drilling Parameters ~n~ ~i~ ~e~f~r~a~c~ .......... 6 Bi t Summary ......................... 7 Dri 11 i ng F1 ui d Mud Components, Quantities and Costs .............. 8 Mud Properties ........................ 9 Casing and Cementi,ng ....................... 10 Special Discussions Si te Survey ......................... 11 Permits ......................... .o 11 Mobilization History .............. · ....... 12 Jack Up Over Location .................... 12 Demobilization .......... .............. 13 Di verter ........................ 13 Leak-off T~s~s' . ...................... 14 Geo 1.ogi c Summary ....................... 14 Figures Dri 11 i ng Time Curve ..................... 15 Drilling Cost Curve ............ ...... 16 Round Trip Time vs. ~e~t~ ................. 17 Well Evaluation Log ..................... 18 Fracture Gradient Curve ................... 19 Maps Daily Plot of Dolphin Position Duri.ng Tow .......... 20 Location Survey for West Trading Bay No. 1 ......... 21 Jack-up Leg Positions ............. ....... 22 Upper Cook Inlet ....................... 23 Appendix Cost per Foot vs. Time per Bit Example of Drag Force Curves Leak-off Tests WELL SUMMARY West Trading Bay No. 1 was an exploratory well drilled approximately two miles northwest of the King Salmon Platform in Upper Cook Inlet, Alaska. After directionally drilling to a total depth of 9087', the well was plugged and abandoned. Operator: ARCO Oil & Gas Company Contractor/Rig: Dolphin International, Inco "Borgsten Dolphin" Began jacking down on location 5/04/79 Began driving 30" conductor 5/08/79 Rig released 6/30/79 Surface location Water depth (MLLW) RKB elevation to mudline 518.8' FEL & 1311.7' FNL Sec 18, T9N, R13W, SM 63' 166' Total dep.th 9087' Average hole deviation Original AFE 23° (.from 4919' MD to 9087' MD) · $6,584,000 Wel 1 cost $4,189,660 (est) Well cost per foot $461 Well cost per day $74,815 Present well status Plugged and Abandoned Total time on location 56 days DRILLING SUMMARY RIG TIME BREAKDOWN Drilling Hole Opening Connection Trip Ream/Wash Circulate Survey Logging Core Run and Cement Casing Wel 1 Control Service/Repair Cutting/Weld Set up at location P&A Demobi 1 i ze Misc Total (Hours) Thru 30" Casing (Mrs) 10.0 4.5 2.5 1.0 5.0 72.0 10.0 105.0 Thru 20" Casing (Mrs) 22.0 18.0 4.5 22.0 20.5 1.O 23.5 28.5 5.0 15.5 12.5 173.0 Thru 13-3/8" Casing (Hrs) 68.0 67.5 15.5 56.5 8.5 20.5 9.5 24.5 22.5 40.0 8.5 4.5 15.0 361.0 Thru TD (Mrs) 225.25 30.0 136.0 32.0 29.5 20.5 28.0 6.5 32.0 · 20.0 26.5 16.5 24.0 77.0 703.75 Total (Mrs) 325.25 85.5 50 214.5 45,0 73.0 31.0 52.5 6.5 46.0 , 100.5 34.5 51.5 72.0 16.5 24.0 114.5 1342.75 % 24.2 6.4 3.7 16,0 3.4 5.4 2.3 3.9 .5 3.4 7.5 2.6 3.8 5.4 1.2 1.8 8.5 lO0.O SYNOPSIS OF DRILLING OPERATION Through 20" Casing Spotted rig on location 5/4/79. Jumped divers for sea floor inspection and started precautionary sand bagging. Rigged up and drove 30", 310# X-52 conductor to 271' RKB. Nippled up and tested diverter system. Ran in hole and drilled 17-1/2" hole to 1242'. Picked up 26" underreamer and underreamed to 1242'. Rigged up and ran 28 its 20", 133# K-55 with Vetco "L" collars with shoe at 1202' and OCT OBS fluted hanger at 227' (top). Cemented with 1250 sx "G" with prehydrated gel followed by 400 sx "G" neat cement. Cement in place @ 2320 hrs 5/12/79. Through 13-3/8" Casing Washed out 20" x 30" annulus- until clear and filled w/gel - LNSD pill. Welded on bradenhead and tested w/5000 psi. Nippled 'up BOPE and tested all valves on the choke manifold to 5000 psi. Tested BOPE w/state inspector present. Ran in hole w/17-1/2" bit and tagged cement @ 1185'. Drilled shoe and cleaned out and drilled to 1252'. Displaced hole with fresh water mud, Ran leak-off test w/13.6 ppg equivalent mud weight. Drilled 12-1/4" hole to 4701'. Ran DIL, Sonic, FDC-CNL, Long Sonic, MLL, Dipmeter and velocity surveys. Opened 12-1/4" to 17-1/2" to 4701'. Rigged up and ran 117 its combination string 72# N-80 & 68# K-55 13-3/8" BTC with Howco SS shoe @ 4690'. Cemented w/2357 sx "G" with prehydrated gel followed by 400 sx "G" neat cement. Cement in place @ 2315 hr 5/26/79. Through TD Nippled up diverter and 20" stack. Nippled up and tested 13-5/8" x 10,000 psi BOPE. Drilled out 13-3/8" FC and tested casing to 1500 psi. Drilled shoe and ten feet of formation to 4711' Performed leak-off test to 15.4 ppg equivalent mud weight~ Directionally d~illed 12-1/4" hole to 9076' with ' average ROP of 10 ft/hr to 35 ft/hr. Ran in hole w/8-1/2" Christiensen diamond core bit and cut core from 9078 to 9087. Ran DIL, FDC-CNL, GR-CAL and velocity surveys. Plug and Abandonment Ran in hole to 4890' w/open-ended 5" .drill pipe. Pumped 20 bbls fresh water preflush followed by 331 sx class "G" cement in 39-1/2 bbls fresh water. Cement spotted 200 feet above and below 13-3/8" csg shoe @ ~'. Made up 13-3/8" Howco EZSV cement retainer and set at 1130' on drill pipe. Picked up BOT 13-3/8" csg cutter and cut 13-3/8" csg @ 1120' and POOH. -3- Nippled down 13-3/8" BOPE Stack and wellhead assembly and set back. Engaged 13-3/8" csg with spear. Layed down 26 its & 2 stubs cs§ equaling 1077.74'. Rigged up and ran in hole to 1120' (10' above retainer and top of 13-3/8" csg stub). Mixed & pumped 300 sx 15.6 ppg class "G" cement. Plug spotted from 1120' to 940'. Made up 20" spear, engaged casing and attempt to back out sub-sea hanger (unsuccessful).. Laid down csg spear and picked up Brown Oil Tool csg cutter. Cut 20" .@ 190'. Attempt to pull 20" without success. Cut 20" and 30" csg @ 181' with BOT csg cutter. Attempt to pull again without success. Cut 20" & 30" csg with BOT csg cutter. Attempt to pull again without success. Cut 20" & 30" csg with BOT csg cutter @ 171'. Jarred loose and pulled two its. Top of 20" csg @ 123' PKB, or 43' above mudline. Layed 200 sx 15.8 p.pg class "G" cement plug from 320' to 200' with top of plug 34' below mudline. Picked up 30" csg spear & attempt to pull without success. Continued attempts to cut & recover 30" without success for two days Divers cut 30" at seabed. Prepared to jack down; afloat @ 0910 hrs, 6/30/79. BIT INFORMATION BIT COST TABLE Twenty-one 12-1/4" bits, two 17-1/2" bits and three 17-1/2" hole openers were used to reach total depth. Below are itemized bit costs for the wel I. Two extended nozzel bits were used. The extended nozzel mill tooth bit, a Smith SDGH, showed poor cost performance as shown by.the Drilling Para- meters and Bit Performance Chart. A long run was obtained with the F-2 with extended nozzles, but its higher cost resulted in an interval cost comparable to other F-2's used. However, the small sample size makes Comparisons highly questionable. Further use of extended nozzel F-2's is recommended before conclusions as to their effectiveness can be drawn. Per Bit No. Size Type Cost Freight* Cost Total Smith Tool Co. 2 12-1/4" 2 4 1 1. 2 17-1/2" 2JS $4355 49.18 3JS- 4355 49.18 F-2 5442 59.98 F-2 Ext Nozz. 7027 59.98 SDGH Ext Nozz. 2598 49.18 DGJ 2783 107.95 4404.18 8,808.36 4404.18 8,808.36 5501.98 22,007.92 7086.98 7,086.98 2647.18 2,647.18 2890.95 5,781.90 $55,140.70 *Freight (Los Angeles to Anchorage)' $23.90/100 lb. Hughes Tool Co. 3 12-1/4" MX-3A 1423 46.06* 1469.06 2 OSC- 3J 1071 46.06 1117.06 1 X-3 1262 46.06 1308.06 4,407.18 2,234.12 1,308.06 $7,949.36 *Freight (Houston to Anchorage)' $23.99/100 lb. Security 1 12-1/4" S-84F 6292 70.00 2 12-1/4" S-33-5 1388 69.00 6362.O0 1457.00 6,362. O0 2,914.00 $9,276.00 Percent of total well cost: 1.7% Total Bit Cost $72,366.06 DRILLING PARAMETERS AND BIT PERFORMANCE BIT '" IDepth Weight on Bit Rotary Speed Drilling Rate Interval Cost Annular Vel' BitI Hydraulic Fg.rma- Nozzel Vel c~on Geologi Horse Power ' No Size Make Type Remarks RKB lO00'lbs RrM ft/hr Dollars/ft ft/min .... HHP/(n2 ft/sec Name Age 117-]/: STCo DGJ ~lrO~OBit 1000 ..... :26"] q ~ ,,, ~. ., , ,,, lO( 2 17-1/; STCo DGJ ,.U~. · ® ,~ T I 26 Serw n ® E . 216 Serw o .e. · e" i T R ...... 17~-1/; STCo DGJ ~tota~s +1(,' ') e) ® . Y T _ 3 12-]/,~ HTCo MX3A .. ~ONO e ~ e e ~) G G N A 20C ~4 12-1/z HTCo MX3A 3000 e e ' (~ '= - ~ ..... E .R ......... ; .. o .......... ~ K y 30( 5 12-!/z HTCo ~ ' 4000 e ~) (~ '' e ~" e ' 40( 6 12-1/z HTCo 0SC3J e ~ ~ ® e ~ . 7 12-1/z HTCo MX3A 42,500 e , ,,, ',~17-1/~ Sec .... 8J17 Half ShiLK. I~ · . ' .............. . . "' ~ ' (~ .... a ) .... .~L:17-1/~ Sec BJ17 Half Sharr~ J~17,li;_Soc 'BJl7 Sh.ro 1s½"~e ....... ' Q e e" .' Dri I/ cr t ' 8 12-1/, SeCl, S-3,3J5 Floats _9 12-1/, Sec S-33. 5 ~i- 5000_ ~) O ~ ...... ~ ........................ 50( 10 12-1/~ HTCo X-3 , Uigh - ' · il 12-1/~ I'Sec S-84 /oraue e ~ I ~ e-' -- e ........ e ..... .... 12 12-1/~ STCo F-2 Change BHI Los]: suFw y " 13 12-1/, STCo F-2 tool w/ex.tende~ 6000 ® : 'e" ~) ~ G <~ e 14 12-1/~ STCo SDGH nozzme5 , - ,.. , ,, , ........... G" 60( w/ex~;endec .e e. ® ~ ~ e> o 70[ 15 12-1/~ ST,C.o'F-2 nozz)es, ~ ~ , ' .................. 16 12.-1/~ STCo 2JS ~, ® e · · ~ ~ e temlock ,,,, 17 12-1/~ STCo 2JS 80QO e 'e. e e G) ~ e 80C 18 12-1/z STCo F-2 e) ~ e ~ e ~ , ~ - ........... lest M 19 12-1/~ .STCo 3JS 44,836 20 12-1/~ STCo 3JS 66,204 ® '~ , . ~ . · ' '~..' '-,G _ ~> ' .....~) 0 21 12-1/z STCo F-2 75,188 gO00 (~ ¢ · ® .. G e ..... G '"Jurassi( Z 90( 22!8_1/2 Chris' 7; e 0 901 Dta,' ~0 Rec 9087 ~ ' ) ~ ' · · . ' " ' BIT SUMMARY Interval & Formation Dri 11 ed Total Bits Used Type Bi t Used (ft) (hrs) (ft/hr) (ft/bit) (hrs/bit)($/ft) Total Total Average Average Average Average Footage Time Penetra- Interval Rotating Interval Drilled Rotated tion Rate Drilled Time Cost Thru 20" csg. Pilot Hole 17-1/2''~ 2 0-1252' Thru 13-3/8" csg Pilot Hole 12-1/4" 5 1252' - 4701' Opened Hole 17-1/2" 3 1252' - 4701' DGJ MX3A, OSC-3J B17J 1252 25.5 49.1 626.0 12.8 324 · 3449 43.4 77.3 689.8 8.7 3449 63.0 47.0 1149.7 189.0 209 To TD 12-1/4" Hole 14 S-33-5, X-3, S-84, F-2, SDGH, 2JS, 3JS 8-1/2" Hole 1 M20 9078' - 9087' (core bit) 4377 189.4 23.1 312.6 13.5 494 9 5 1.8 9 5 DRILLING FLUID Aquagel Baroid Ben Ex Bicarb CaC12 Caustic CC-16 DA-425 MUD COMPONENTS, QUANTITIES, AND COSTS 2876 sx $39,803.84 Defoamer 64 sx $4,620.80 1460 sx 17,184.20 Lime 21 sx 316.68 75 sx 1,170.75 Micatex 40 sx 745.60 11 sx 401.39 Q-Broxin 354 sx 10,786.38 176 sx 4,755.52 Soda Ash 39 sx 1,000.35 303 sx 8,402.19 Wall Nut 60 sx 1,147.80 87 sx 2,395.98 .Tech. Serv. 46 days 14,490.00 35 sx 3,639.65 Soltex 270 sx 28,795.50 Total Mud Cost: Cost per day (total time over location)- Cost per day (operating time)° Cost per foot: Percentage of total well cost: $139,656.63 2,493.87 2,685.70 15.37 3'. 33% Weight (lb/gal) API vis (sec) Plastic vis (cps) Yield (lb/100 ft2) pH Solids (%) Chlorides (ppm) MUD PROPERTIES T.hrough 30" 9.0- 9.5 37 - 48 6-7 7-17 10.0- 10.7 5.5- 9.0 850 - 1680 Through 20" 8.1 - 9.3 4O- 54 10 - 20 4-14 9.4- 10.2 3.0- 8.0 1 500 - 2700 .Through T,D 9.4- 10.0 40 - 46 14 - 22 5-12 10.2- 10.8 11.0- 14.0 1800 - 4300 SPECIAL DISCUSSIONS 30" CASING & CEMENTING SUMMARY Drove 30", 310# X-52 to 271' RKB with 405 blows for final foot @ 105' below mudline. 20" 1210.04'. Howco SS shoe @ 1202.48'. 28 its 133# K-55 with Vetco "L" collars. Cemented casi.ng with 1365 sx "G" with 2.25% prehydrated gel, 3% CaC12, and 0.03% N?I, followed by 400 sx "G" neat cement with 3% CaC12 and 0.03% NF-1. 13-3/8" 4708.06'. HoWco SS shoe @ 4690.06'. ll7 its 72# N-80 & 68# K-55 BTC Cemented casi.ng wi'th 2357 sx "G" cement with 2.25% prehydrated gel and 2% CaC12, followed by 400 sx "G" neat cement. Si te Survey A consulting firm, (Dames & Moore) was retained to perform a subsurface survey of the proposed well site at and around latitude 60° 52' 22.56", Longitude 151° 38' 05.71" Sidescan Sonar located an underwater pipeline running from the Monopod ~latform to the Trading Bay Unit Shore Facility within 40 feet of the originally proposed surface location. Due to the strong tidal current within Upper Cook Inlet, and a possible inaccuracy of the Sonar's measurement, the surface location was moved 750' northeast of the proposed location. In addition, a total of six (6) three foot diameter orange buoys were dropped along the pipeline's route as a precau- ti onary measure. Geophysical studies and subsurface soil samplings were then conduted at the final location. Subsurface sample investigation to 20 feet below the sea floor was accomplished using a Vibracore sampler. Samples of the near-surface soils were also taken approximately 330 feet to 610 feet of surface range from the drill site. Seismic profiler records indicated the presence of a thin surficial sea- bed formation (fine to coarse sand.with gravel) underlain by more than 90 feet of glacial silty sand. VibracOre samples consisted of two to three feet of fine to coarse sand with gravel which appeared to be loose to medium dense in place, followed by very fine sand medium dense to dense to depths of approximately 10 feet, and medium dense between depths of 10 to 20 feet below the Inlet bottom. The soil bearing capacities and shear-strength were evaluated and estimated. Six to ten feet of leg penetration was predicted. Actual .penetration was eight feet. Permits Both state and federal permits were obtained for this operation. Federal Permits' Permit to Anchor: Department of the Army, Corps of Engineers. Permit required to anchor a drilling vessel to conduct exploratory drilling. Applied for February 23, 1979. Received May 4, 1979o NPDES Letter of Non-Objection: U. S. Environmental Protection Agency. Outlines and permits discharges overboard stipulating maximum flow rates and contamination levels, as well as test & monitoring procedures. Applied for February 5, 1979. Received March 13, 1979. State Permi ts' Air Quality Control Permit- Department of Environmental Conser- vation. Allows operation of one Otis crude oil disposal unit with stipulations on efficiency of burn, wind direction and force during operation of unit. Applied for March 19, 1979. Received April 25, 1979. Waste Disposal Permit' Dept of Environmental Conservation. Covers disposal of liquid industrial waste. Applied for February 2, 1979. Received April 25, 1979. Permit to Drill' Division of Oil & Gas Conservation. Approval of drilling operation. Applied for January 22, 1979. Received April 12, 1979. Certificate of Reasonable Assurance' Dept of Environmental Conservation. As required by Sec 401 of Clean Water'Act for anchoring of a drilling vessel. Lease Operations Permit for ExploratorY TeSt Well- Department of Minerals and Energy Management. Applied for January 22, 1979o Received February 27, 1979. Mobilization History The Borgsten Dolphin was towed from Hakodate, Japan to Homer, Alaska, a distance of 2576 miles (see attached map with daily plot of position on page 20). The total time required for the voyage was 40 days. Nine days were spent hove to due to severe weather. Seas were encountered up to 40 feet high with winds of 60 knots. Conditions were such that another boat was dispatched from Japan on March 23rd with survival suits and other cargo for the tug. The rig sustained damage that was to later require repairs. Underwater Construction Co. was hired by Dolphin International to do the repair job at the direction of ABS, Noble Denton & Associates (Insurance Co), Mitsui Ship Buildi.ng & Engineering Co. (rig builders) and Dolphin International. The major repair involved welding the fraction and diagional connection above the water line. Alaska Indus- trial X-Ray performed ultra sonic testing and was witnessed by two (2) ARCO meteorologists. Total repair job took 9 days of rig time which was 100% contractors account under the provisions of the contract. Considerable co-ordination and integration of many different groups and services was required in readying the rig for drilling use. On April 17, 1979, C. R. Knowles called a meeti.ng t° finalize plans for the rig's arrival, location spotting, and jack up. Twenty-three people were present including ARCO Oil and Gas personnel from the Dallas, Anchorage, and Kenai offices, Offshore Logistics, Dames and Moore, Itech, Nortec, ERA Helicopters, and Dolphin International. Cook Inl.et weather patterns were reviewed, geo- technical survey results discussed, jack up timin§ strate§y presented and pre-plot requirements for rig positioning were co-ordinated at this meeti.ng. Jack Up Over Location High tides presented a potential problem with spotting the rig over the location. The rig was to be spotted on high slack tide. As the tide built up to high slack, towing force would change from an estimated 150,000 lbs to zero at high slack. Further complicating the problem was the additional drag force imposed by increased surface area as the legs were jacked down. Tow force curves were developed by Frank Schuh, Sr. Staff Drilling Engineer,'covering high slack tides over an interval several days either side of the estimated spotting. A "window" was thus created showing when jacking down of the legs (at one foot per minute) should begin, respective to tide levels, as well as when abort operations must begin should the rig not be jacked down properly. An example curve is included at the back of this report. The rig was spotted smoothly on location at 1245 hrs 5/04/79, encountering only a slight problem with one of the tugs. Divers were jumped immediately for sea floor inspection and started precautionary sand bagging around legs to reduce scouri.ng. Demobi 1 i zati on Following plug and abandonment of the WTB #1, the rig was prepared to jack the 1.egs up and move to Homer. Divers checked' the subsea well site and found it to be level with the sea floor. A Cook Inlet Marine pilot and a fisherman's representative were on board for the move. Radio con- tact was established with the fishing fleet and canneries. The Coast Guard, Corps of Engineers, Homer officials and the Alaska. Department of Fish and Game were also in attendance. The rig was jacked into transit draught at 0910 hrs on 6/29/79 and towed to Kachemak Bay with M/V Marlin and M/V Vigilant. The Borgsten Dolphin arrived in Kachemak Bay at 2215 hrs 6/29/79 for repair. Diverter The Dolphin was equipped with a 21-3/4" diverter and 20" Hydril. It was thus necessary to underream for 20" casing. A 26" bit would have provided a more reliable method for obtaining the large diameter hole. However, obtaini.ng clearance for that large of bit would have required a 29-1/2" Hydril. A 29-1/2" Hydril was located, but mobilization would have taken several days, as well as modifications to the diverter system. Given these two facts, it was 'decided to proceed with the underreami.ng job below the 20" Hydril and 21-3/4" diverter. -13- Leak-off Tests Two leak off tests were performed on WTB #1. These tests are included in the Appendix. The first test was run immediately below the 20" casing shoe at 1242 feet. A total of five and one-half barrels were injected at 1/2 BPM, yielding a curve that deviated considerably from the minimum pressure volume line. Increasing the pumping rate to 3/4 BPM produced a closer fit to the minimum pressure volume line, and resulted in a calculated equivalent mud weight of 13.6 pounds per gallon. This can be expressed as a fracture gradient of 0.706 psi/foot. The second leak-off test was run below the 13-3/8" casi.ng shoe at 4711 feet. This time pumping rate was increased to 0.9 BPM and produced a curve very closely approximating the minimum pressure-volume line. Leak off occurred at a calculated equivalent mud weight of 15.4 p. pg, for a fracture gradient of 0.799 psi/foot. Geologic Summary West Trading Bay #1 was drilled to test an anomaly located updip and .to the north from the McArthur River Field across the Trading Bay Fault and downdip to the west from the Monopod feature. The trap was believed to have been formed by the Tradi.ng Bay Fault and a northwest trending cross-fault. However, only minor non-commercial oil shows were encountered through trace C-4 with 72% water saturation. The Trading Bay Fault probably acted as a barrier to oil migration into this' block. Reservoir sands were present throughout the Tyonek and Hemlock sections and their quality is comparable to other Cook Inlet reservoir sands. The structure appeared to conform to seismic mapping since for the most part dipmeter readings were in the range of 5° to 20° generally in a westerly direction. I interpret any anOmalous readings to represent cross-bedding and foreset bedding in preference to faulting in the lower half of the well. J. G. Cvitash 8-7-79 -14- · FIGURES ~ ~co o.,,~ ~-~- co=r~.~ o DRILLIN-~ TIME CURVE DAYS WTB Well N,me ="'~' __ Field Pre.areal by F. V. Anal eton I I L~tio, Cook Inle~i,u~t.S.Alaska 0 20 30 40 }0 70 80 90 10 120 130 140 ~ I/ Drive 30" co~ducto' 3rill 12-1/4' Ope'~ to 2~i" Run iO" cs; · ! !.1 ...... 12-1/4 ._ Opel to 1 -1/2" ! ~ Run 1 t-3/8" cs§. .. , . \\, ' ' .. Drill 12-1/,." hol( & cove ..... ........ ~mobi 1 ~ zatio~ I I' ! I , ! I I I , ..... ,, ........... Actua ' Estim~ ted ..~ ,,. ,. 1000 2000 ! . 9000 I"! o,ooo 11 14,000 16,000 17,000 18,000 19,000 ~f~ C° Oii and Gas Company 10,000 *DRILLING~COST CURVE WeliNam® WTB #1 Preparedby F. V. Angleton II , , *'~,-,-.,~.,.,,~~ COSTUNITSn ,~ ~0 D XIO,O00 ~], XlOO,OOOField __ Loc,,tion COOk Inlet~,~,:~ S.Alaska / 0 20 30 40 50 60 70 80 90 100 140 15 ~.v vv -~v vv v~ ...... · t Drive 30" Ccnducto' Drill 117'1/2" hole, open to 26" · --"i~ [ Run 2(~" csg. · i I Drill 12-1/z" hole, oper to 17-1/2" ! · l~Drill 12-1/4" h~le $ :ore r Demobi 1 i ze O 0 0 ~0 ' . 0 ' .......... Actual Estimated ~0 ~0 ~0 1000 2000 4000 5000 8000 9OO0 11 12 13,000 14,00(] 15 16,000 17,000 18,000 19,000 ABC Oi. :~r~d Gas,Company ,,r"~' Well E,~lua~,,on Log DRILLING RATE FT/HR Field PORE PRESSURE LBS/GAL MUD WEIGHT FRACTURE LITHOLOGY FORMATION GEOLOE¢iC LBS/GAL GRADIENT NAME AGE DEf,t,':!;tT¥ GM?CC CONDUCTIVITY MtLLIMHOSIM SONIC LOG ~A,T uSECIFT 2. 8 10 12 14 16 18 20 ~ i ...... l~ ~::_:_:~::t,:' ,: .... i .... i..: .... t:::::: ..t .... , .... , ............... , : ...... ; ... :.:~ ::::::::::::::::::::::: . ..... o ~. ; . .. -:'--:.::-:.::-~,:-:::,.:.-~':~:~: ~ : ...... . . . ............. :~:~-:~]:~]~]]~].~]~]. ~]] .'...::~.-:~::: :~:'.:::: : :'~::]]]:]]~:??~:?~:~{:.::~::~:. ,.. ::...~: : .... :'. :::::::::,'::::::'.~ .. : ~:: ': .... , .... ... ~:: . : : ; ~' "~:::~:. 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'~:::::::~ ' ,,.. .......... :.:~l.-,..~-:x- .... ~::;]:~]].::_2]'.LLZ.t':t:~: .'~ z: ~:: t L~t ~::L:: ' · ~ ·: ' ' ~ ............. ~. t ' · -, ....... ' ................... :,.~ .......... J .... , .... i .... ,,.,~. ~:~.~t~::'~'t:~:]:;::;7:?~ :::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::: ..... ,::::: ........ ' .... : ................. 2oooo ROUND TRIP TIME VS. DEPTH 12 11 I0 9 8 7 6 5' 0,000 9000 8O00 7000 6000 50OO MD feet~ 4000 3000 2000 1000 o Fracture Gradient il 1~ 13 14 15 16 17 18 1000 2OOO 3000 4000 TVD 5OOO 6000 7000 8OO0 9000 MAPS 0SljlmO UtS'.M&yi o · · ~AAN- BAAT~ MONGOLIA H I 8 [ T HlHqnl° ! N Ch'lfll.tU 0 PEI.P'ING · . K'li'fl~B~ 0 K'ummmI ._ ~.~-;?. .... Ch'dml-$hl o NIa.chM Fu.Chou H$ia.men OH, Vl&d,vOIl~k Ch'~ngjlh S£A OF JAPA~ ~i SEA OF OA'IIOT~K .,, i oSiymchaA .. · Sum;Iv Jhne Shlnl-hii · BO~IN __' :'~.U~YUBV J~ ~ ~,~:~MH~ S~.' ~ IS~O5 ~ .. . . .. ~ J~ · AN/ - ,4 / / ./ 3£A t P A C I T H C E A N .... · ,, .$1A¥ · reda Strait 6'04'S. 05'50'E. NOON£ Lombok Strait ~°50'$ · .-. ,'- ~ -. G~ -' . . .. .. . . · ,~ I . : .. .:. ,/~6 b.. "'"' ,',~, .hu, ' '%' · .. · BISMARCK Nev,'..O.,M kbd ' N.M,~"% . h,.",*m Gi&,d PHOEniX ~ND5 t~' ~' ~ '~' ' ' .~eJ~ ~. ' ;~ l X ~KE~U , ~ k ISLANDS . ~v~. J ~1,, We,i* % SAMOA IS~NDS I Y:? 516 612 X: :>05 500. 51 I 35:5 2:03 366 OPERATOR --. RIG AREA WELL ARCO BERGSTEN DOLPHIN UPPER COOK INLET SECTION 18,T 9N, RI:SW~S.M. WEST TRADING BAY No.I Y= 2 516 480 X= .208 7:>1. 515.8 Y=2 511 ::>02 X= 208 602 CERIFICATE .OF SURVEYOR I HEREBY CErtIFY THAT I AM PROPERLY REGtSTERERED AND SCALE: I" = I000' NOTES: I. Location of well site was occomplished by using' trian- . ~lulation stations "$CREW"~ "TAD' end "TRADING BAY'. 2. Ail dimensions ond coordinates are in feet. ALASKA STATE PLANE COORDINATES ZONE 4, FEET. Y=2 515 18:> X= 208 176 GEODETIC POSITION LAT. 60052'27.87" LONG. i 5 i o:58' 15.6;2" LOCATION SURVEY FOR WEST TRADING BAY No.i SECTION 18~TgN~ R i:SWiS.M. LOCATEO IN UPPEr COOK INLET LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY SUPERVISION~AND ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT. ' 7/~:--v. ,/177 -, DAq' E' SURVEYOR ATLANTIC RICHFIELD CO. SURVEYED BY INTERNATIONAL TECHNOLOGY LI,MITEp ANCHORAGE. ALAAKA HOUSTON. TEXAS V C ENTE R OF LEG X LAT. 60° 52'2:'t.i?" LONG. 151°$8'16.0:5- Y::~ 515 !12 X'- 2:08 154 ALASKA STATE PLANE COORDINATES, ZONE 4, '. FEET. ~-='~ LEG LOCATIONS DETERMINED MAY 4,1979 FOR BERGSTEN DOLPHIN- --- CEHTER OF LEG LAT. 60°52'27.92" LONG. 151°~,8'14.14'' Y=2 51.5 185 X= 208 2:49 LAT. 60°52' LONG. 151 Y= 2 ,515 062 X= 208 268 OF LEG JACK- UP LEG POSITIONS UPPER COOK INLET WEST TRADING BAY No.I SECTION 18 ,T9 N,R 1:5 W, S.M. SURVEYED FOR ATLANTIC RICHFIELD CO. SURVEYED BY INTERNATIONAL TECHNOLOGY LIMITED ANCHORAGE, ALASKA HOUSTON. TEX~$ - T 10~ Tg 35 t.. , APPENDIX I-~~ ........... ~ ' : ~ i, , '.iI . . ~! _.i:k,,. ! ~ , : ' , L~',. :',h~lm ",.~-.m~~ , ' ~.::~i~ i !~ /~ : /-/ !r7r ~,'z-~~- 'i , . ~ j ~ t~ ~ .I · II , I i j ~ , . ,~, '' , '1 , I t,, ' ~' il!i:J ' ' ; ' I ' I ~ I ' J~ , ~ ,,' ' : i I ,' ', ~ ' ' ' :' ' ' i ' · , J I , ' '' : '' '' t , i, i.l,. ' I ' I ~J ' : i ,~ i~ i i i I ~ ~'I l ~ I I i ' ~ , . , , I ~ , ' I II 11il ) ' I ! , i ~ I 111111 I I ill ' , , ~ · : * ~ ' ' I ' ' ' * ' ' ' , ~ ' I ~ ; , , I , i I : : ' I ,. : · i' I , iI , , , , ~ ~ ,,~ ,i , I i~ii~ i~i~ i i ',,1~' ',,,,~ ',-,,,,'"~' ,;~ ......, , 1'~ I i ill, , ~ , ~ Ii ~ I , . , ,, ...... ~ II .I~ : ' 'a ' 'i ' i '' :'' ' n' ii~I 'i '' ~ : , i ' : '' i n ~ I,. ,,. , ,. ~, . ~; . . ; ~ · , I I ; ' ' I ' I I ~.. ~ , ~ ;! I ~ II ~ ! i :, ~r : i i ~ ~ ~ , ~ ~ i : : i i I I L~ , i i i ~ I i I t I i t i i ; i ; i ' i iI ,~ ~ ,, I .... Il' ~ ',i,, ~ , ~ I ,I, I. I ~ I , . . ~ .... ~ , , ~ ~ , , ~ i ~ i ; i'~ i i ' : ; , , : , ~ ~ I ~ f ii ' ~ : , i: ':i' ,~'~,I~I ,! ~,~i ~,~i!i~! Ii~!~I~ ...... ~i,.~!~!i . , 900 /00 350 ~00 IS'O //0 ~o , '"-'~'i ' :- ; ' ",, , ' : I i' i ' " - , , , ,' , · i t'i I i ~ i il ' , I ii ~'I i :I ~ ' I~ I ' I I I , I , ii I' ' I I ~ , · i I, ' , t , ;i!, ' - ' ' ~ ' '~ ' ' : , , ~; ; i i i ; i ~ : ; i -I i i i i I ' , ' , , ' ' .... , I ' 't' ' ' ~i i i 'I '1~ ~I 'I~ I '; ~' -~ I ' i ' ' I ........... ~ !~ ~! i, i ill I ! i I ~:~,,1!1 ~: r!,::_~__z_~4 : , · ' · '' i~ I Ii ~ , ' ' ~ ~ ........ ' , ' ~ ' , . i 'i i~ ~---T---:-, ,,~, ,--7-~--~ ........ .... ~20 I ~lb I i /~' IL /7 i;~;'~~ *;,:: ~ i, ~ ~ ~I, ,'1 ':~ ; :tll ~ , ~,, ii ' ~i III i''~ ~iii i I 1 I I *' * ~ ~1, ii~ ,i i~ iii ~ I i ~ i I i~1~,~ il I I1 ~ ' I i~i~,i1~ !' ii ti!t~l ~ ~ I ~ ~! i~ ~ Itl .... ~" ~ ~i t ~: ~ ; ~ ; ~ ;~! t . ~ ' ~ ~ ' ~ , ~ ~ ~ ' ~' ~, : .~tl , , ~ , ]1,~. , ,, ..... 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[ : , ,~ · : ~ ['-i= ~ ~ f : ~ ~ i r ~:_: i ~ ; ~ ,~ ~ :~': ~ ~ ..... ~.'--t i i ~ : :.X~ i:ilSl~i , , [ i:~w,-i ; -,.L..r2:i~q~:~,, '..'..~,.~,t ~,~'~, =.-.,,~tt'~: : : -':~.~_]ti ~J~~Jj~..~t~ii-~.Jj t :.l.. [ , : : . i ,l 'llI'l ' I ' '! ' } i i ~ ' i'~ .... T't i ! t i t t I:ri''l 1 I i ! t ~ 1 --' ~ i } : il j~ J I i I ! I ['i~5--J i t I--I I iFF 'J I I '--~Z4---I I ! : J ' t i ~ ] i J i~ .J [ j I I I--J I']' I i ~ ...... t --'.:l--J J ' I I J : · ,.' ' ' . . ' ' ' ' ' ' I'. J'j:..j ! i ! I I i ! i. t i i i iii'l-i~ ! ~ ' }~ : . , I ~'; r J i i j ' ' !"* ~ [ :"] i I ~ . ] ] l]._L ['[ [ i I [ J-I.I I l.l'] !l [ I'-[ I I ~[~ I } I I ~ i i i i i~i~ i I I i t '-LJ'J i ~'~'! J J ~ i J I ~ J l_: ~ I I I I'[L'ZI I I l . , [~t ~ i J .~l~j ! i j I i i I i li']']_'~ I ', ] ~ . ~ ~/J J t ! i "[ ~ J_i ] ~ ~ i i' ..]ll~.__[ '71 ] J } i ~ : I i i'~'i- '~ i ' ~ i ~ I ~'~-- I I ~ I i ~ '[ I -- .... 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C't~ ,[ 323 AtlanticRichfieidCompany · I '0. AtlanticRichfieldCompany ~, (- C ISubjelFt L~9 g = $.0% sc.,.. AtlanticRichfieldCompany Page No. , ~._ .. +- .I5, 0 ~'2...,-.I'~ W ~ '~ --t- 0.~ '~L.~ 9.~f~- q-7o6 ARCO Oil and Ga: ~mpany South Alas~,., District Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 July 24, 1979 Mr. Hoyle Hamilton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Hamilton: Enclosed is the finished Well Completion Report for West Tradi.ng Bay #1 Well. Si ncerely, C. R. Knowles District Drilling Superintendent CRK/LAE/dac Enclosure. cc' WTB #1, ll.A.3 ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany Form P--? SUBMIT IN DUI ~.TE* STATE OF ALASKA ($eeother in- structions on 5. API NIYlVLEHiCAL CODE reverse side) OIL AND GAS CONSERVATION COMMITTEE 50-733-20325 ~ 6. LEASE DESIGNATION AND SERIAL NO. WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* ADL 18777 la. TYPE OF WELL: OIL,,.ELL [~] ~*SWELL ~-] DRY ~r] Other Wildcat 7. IF INDIA_N, ALLOTTEE OR TRIBE NAlVlE b. TYPE OF COMPLETION: N/A W,LL OVEa E.~ BaCK nEsva. Other P&A 8. eN~'~,F*~ o~ ~s~ NAME 2. Na.~. oF OP~aaTO~ N/A ARCO 0IL & GAS COMPANY . Alaska 99510 FLI~LD A,ND POOL fOR w~[LDCAT P. 0. Box 360, Anchorage, ~. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* ui 1 dcat At surface 11. SEC., T., iR., M., (BOTTOM HOLE 1312' S & 516' W from NE cr Sec 18, T9N-R13W, SM O~EC~VE~ At top prod. interval reported below N/A '~ Sec 8, T9N-.R13W, SM At total depth 35' S & 250' N from NW cr Sec 17, T9N-R13W, SM ~-~. ~-"?.?~": i ~"7~9~IT~°' 5/4/79 6/20/79 I 6/20/79 166' RKB to mud line ]20" Braidenhead : a 1 ?E ~' tn m~dl ine 18~ TOTAL DEPTH, MD & TVD[19. PLUG, B~CK MD & TV'Dp. IF 1VEULTI~PLE CO1VLPL., 21. INTERYALS DRILLED BY ~-~OW1VI-ANY* ROTARY TOOLS '1 CABI,E TOOI.,.~ 9087'MD, 8780'TV~-- 180'MD,. 180'TVD [ N/A All Intervals 22. PRODUCING INTERVAL(S), OF THIS COMPI.,ETIO/q--TOP, BOTTOM, NAME (MD AND TVD)* 23. WAS D~REC'r~ONA. L SU[tVEY MADE · ! YES NONE 24. TYPE EL2EC~IRIC .~ND OTHt~ LDGS RUN DIL, Sonic, FDC-CNk, kan9 Sonic, MLL, Dipmeter, Velocity Survey CASING R~"COI{D (Report all strings set in w~ll) C.t~SLNG SIZE \VEIGI-rr, LB/FT. DEI:~ Sa!IT (1VID) I-IOLJg SIZE CF.~%ILNTING RECOi:hI) 30" 3]0 27] RKB Driven - 20" ] 33 ] 202 3- 72 4690 AMOUNT PULLED 26. LINEr{ iR~COBI) NONE 28. PEP~FORATIONS OPFaXl TO PRODUC~Olq' (Interval', size and number) N/A i i i Pl%ODUCTION 20. DATE FIRST Pi%ODUC'I/ON N/A 27. iUBING HECOP~D SCREEN (MD) SIZE DEPTH SET (MD) ]PACKER SET (MD) NONk i i 29. 'ACID, si!aT, F~%~kCI'URE, CEa~IE:NT SQUE,~ZE, ETC. PI~o:DUCTION MEi'I{O'D (Flowh~g, gas Ii/l, pumping--size and type of pump) N/A oIL--BE L. GA.S~IViCF. [HOLTERS TESTED '[CHOKE SiZE ]PROD'N FOR I t FLOW, ~BING~ [C~G P~SS~ [CAL~~ OI~BBL. ~/~ ~/ ~ ~/a 31. DISPOSITION 0F GAS (Sold, used ~or ]uel, vented, etc.)' N./A I N/A I J N/A j N/A [ N/A WAZI~-'R~BBT,. IOIL GiR~VIT¥-A-PI (~OZ~.) I N/A J N/A ..... t TEST WITNESSED BY N/A 32. LISTOF ATTACHMENTS Directional SurVey 33. I hereby certify that the foregoing and at.tached information is complete and correct as determined from all-available records SIGNED ~ ,' ~ ~ ' [%~ TITLE }i~trict Oral 1 iud Supt. *(See Instructions and S~ces lot Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well comp!etlon rel3ort end log on all types of lanJs and leases ~r'~ Alaska. item: 16: Indicate which elevation is used as reference (where not otherwise shown) for deplh measure- ments given ~n cther spaces on this form and in any atta~hmenls. Items 20, and 22:: If this well is completed for separatc production from more than one ~nterval zone (multiple completion), so state ~n item 20, and in Ite,~ 22 show the prc:Juc*rt9 interval, or ~ntervals, top(s), bottom(s) and name (s) (if any) for only the interval[ rel)orted in item 30 St~bmit a separate report (page) on this form, adequately identified, for each additior~al interval to be seperatety produce:i, show- ing the additional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoul:J show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately producad. (See instruction for items 20 and 22 above). 34. SUMMAItY OF FORMAl'ION TF-~'I'."; IN('/,UI)IN(; INTF..IIVAL TIES'FED. PI1E."LStJI1E DATA AND I:LECOVERIIF~ C)F ()IL. GAS. 35. G ]~)LOG IC WATER AND MUD ,, NAME M£AS. Tyonek 3210 321 0 "E" 4800 4800 No tests were made. "F" 6040 5976 "G" 701 3 6861 Hemlock 7920 7697 West Foreland 8345 8093 Jurassic 8660 8385 For descriptions of the]~ho]ogy & fractuPes, see ~e]] da~a package fop c9~e description Pepo~t and s~de~a]] sample descP~pt~on. ThePe were no apparent d~ps o~ detected shows of o~3, 9as o~ wa~e~. S~de~a]] Core Samples Porosity , 76~9' 8097' 26~ .. ...... , ,, ........... Operator aad well name ARCO Oil and Gas West Trading Bay %1 Location Upper Cook Inlet, Sec. 18 T9N-R13W, 1312' FNL, 516' FEL Shot20 lRec°vered Depth 8425G 8420L 8417L 8413G 8097L [.3/4'~ % Oil Description stain Sand: light gray-broth, friable, 1-2% moderate sorting, med. to coarse grained with occas, chert pebbles, angular to subromnded, quartz, with chert & qreen li%hics; soft white ashy clay matrix. Sand: A/A with very fine to silty grains in the matrix clay. 1-2% 16 Oil flur, r Show Intensity sum trace Fair fair trac~ Fair fair Sand: A/A, fine to coarse-grained 1-2% clear & white qtz, scum chert (dk. tra_c(. Fair fair 8095G 8092G 7868G gray to black), green and red volcanic lithics, white soft clay Remarks L - lithology; G - geochemist_!~fi__P__-_jp~l_yllo!ogy Sample fluor my be dominantly mineral fluor AR3B-2390 Described by N__aD_cy G.. Pe~ttermon. ~t~aficRichfieldComp,-~¥ ~. Operator and well name ARCO- West Trading Bay ~.1 Location Upper Cook Inlet, Sec. 18 T9N-R13W, 1312' FNL, 516' FEL Core number ]Interval ~1 / 9078 - 9087 Core Description Report ................................... l~-a · 1o' [ 6/18/79 9.0 I 7.0 Depth 9078.0-9085.0' 9085.0-9087.0' Thickness 7 ft. 21 Description __I~f_M_oc_l_~s_~J~c_vo~Q._ani~s% ~e_.ry._fine. to_fine_grained, green_and white fibrous to 'radially. fibrous_crystals...of__chlorite~_and zeolite (?); the minerals are moderate!z_spf%[_¢p~~e~..._~_.u~._ to coarse magnetite crystals altering to iron oxides, wi-th red iron oxide staining the rocks, rinmting phenocrys-ts, and coating fractures; core is very broken up with most of the rock altered to chlorite,-zeolites, and clays; the vg~c__an_~s~a~q.~_a_d_~y fractured and fractures are cemented with zeolite and some calcite; top of the core is very weathered to soft, sticky, green clay and maybebrecciated - could be a fault zone. No Recovery. Core number AtlanticRichfieldCompany l'o Mr. Harry Kugler Division of Oil and Gas Rfiafia ~f~A3_aska 3001 Porcuoine Drive, Ancho.rage~ Alaska 99501 From Enclosed [] Under separate cover [] Via l~*cord Of Shipment Of Confidenliai informalion IDistrict South Alaska W. S. Estes ARCO Oil and Gas Box 360 Anchoraqe_~. AK Subject ARCO West'-Tradinq Bay. #1, Lower CoOk Inlet, Alaska A.R.Co. map number .. Quantity Description ~1 Sepia ~ BL ,Se~ia ~1 Seoia BL Se~ia BL Sepi~ BL Sepia .Sepia DIL, .5'_'~_ 1202-9060.¢ ._Run i and 2 · DIL~ 2'~.~ .1202-9060~ Run 1 and 2 BHC~ 5,~ .900-9050~ 'Run 1. and 2 . B'HC~ 2"~..90.0-9050, .Run 1 and 2 ~... · ?DC~ 5"~ .300,9034, 'Run !.. and 2 · FDC-CNL,...5", 300-9034~ Run 1 and 2 proximity Loq-Microloq, 5".~ 1202-46.94, Run 1 Continuous Dipmeter, 5"t 4694-9033, Run 2 ContinUous Dipmetert. 5"~ 1202-4679~ Run 1 LSSonic 10~-12' ~ 2"~ I202-9056', Run 1 and 2 . LSSonic 10'-12".,. 5"~ 1202-9054', Run 1 and 2 Arrowplot': 4712-9022'_~ Run 2 Cluster Listing for Arrowplot Mudloq, 265-9087, 995]_0/ Core Description Report, 9078.0-9085.0'and 9085.0-9087.0' Side~all Sample DeScription, 7342G-8425G Core sample~ 9078-79~ 9079-80, 9080-81, 9081-82, 9082-83, 9083-84 9084-85 Note--Please verify and acknowledg~ receipt, by signing and returning the second copy of this transmittal. ~'~" CO__M_M' ~"E5 ENG ! -i~ 'GEoL STAT TE~ STAT T~~ CONFEr: ' FILF: IDate 7/23/79 Signed by Colleen Rutledge Remarks ~"~'" A~3B-1370-D J! D~EC T~ON~ £ ATLANTIC RIC~IELD COMECANY COMPANY ¥¢EST TP~.DiNG BAY NO. ! WELL NAME COOK IR~LET., YZLASF¢. LOCATION JOB NUMBER A679 S0.555 TYPE OF SURVEY Magnetic Multi Shot SURVEY BY Bob Kiser ,')FFiCE DATE 6-21-79 /' O. L~ox 4. 1.9?O/Anchorage. Alaska 99509/'(.907) 349-4677 , ~'~'X 910-83 I- 50.:75,'"C~blc: EA$ TCO June 26, 1979 Atlantic Rich£ield Company P.O. Box 360 Anchorage, Alaska 99501 Well Number: West Trading Bay No. 1 Location: Cook Inlet, Alaska Type o£ Survey: Magnetic Multi Shot Method o£ Computation: Radius o£ Curvature Date: 6-21-79 Surveyor: Bob Kiser Job Number: A679S0333 ATTN: Marion Brooks Dear Mr. Brooks, I am enclosing the original and one copy of the Magnetic Multi Shot Survey run on the above mentioned well. We wish to take this opportunity to thank you flor calling on our services and trust that we may continue to serve you in the future. Sincerely, EASTMAN W-HIPST.0CK, INC. ) ' ,., ~ / . Janes T. DeMonia District Operations Surveyor cc: file eno. hiAGNE'IrIC MULTI-SttOT SURVEY 2,.5 JL~N£ 79 TRUE '-]qE~'.qUR'ED- VE'RT! CAL "..SUB DEPTH DEPTH SEA TOTAL,. COORDINATES ...... 1' 000 -- I'~, 00-;~9 02 · 2000 2000. 1902, 3000 3000, 2902. ............ ~'OOO -- ~'O"O 0 ~ ......3'902 · 5000 Z~999, 4901, 6000 5946, 5848, ......... 7DOD '6~2i-~675~, 8000 7771, 7673, 9000 8699, 8601, 0,00 S 0.00 0,00 $ 0,00 973.28 N 580.57 1288.27 N 779,61 [] SURED DEPTH AND OTHER DA TA FOR EVERY 5£A DEPTH. HEASURED DEP TRUE v'EtA-T-I'CAL--~'U fi M 6~'TV6 DEPTft SEA DIFFERENCE vE~TTCXL CORRECT ION TOTAL COORD INATE5 7378 7198. 7100 179 8 74fl7 7298. 7200 189 10 ...... 759'6 7704 7498. 7ilO0 206 8 7fl13 7598. 7500 215 9 '-7920 ................. 769Bg ...... 7600 .........222 ..................................... 7 ~028 7798. 7700 229 7 8135 789~. 7800 237 8 ..... 82¢2 7g'98%~-79002~'4 7 8350 8098. 8000 252 8 8457 8198. 8100 259 7 .... 856'5 E298~' 8200~'267 B 8673 8398. 8300 275 ~781 8498. ~400 282 7 fiB~9 B59B';'~BSUO ...... 291' 8998 869B. 8600 300 9 767.98 N ~56.74 E 805.08 8'4'I';'69-7~ ........... 502~06 .... 877.84 N 523.63 913.66 N 544.36 E 943.25'N ........ 981.fi0 N 585.90 E 10Ia.78 N 6G6.OI E 1047,'79"-M ................ 625'~Bg'"E ............................................................. 10~1,48 N 646,~B 114B.83-~I .... 689~81 E ........................................................ 1216.89 N 733o57 1251~8~'-S ........ 755,~-E ................................................................................... 1287,61N L] \$URED DEPTH AtND OTHER DATA FOR EVERY EVEN 100 FEE, T OF SUB SEA DkPTH. T RUE --MEASURED ......... V E R T'IC A I.:--$ UB---/q D~T VD. VERTICAL DKPTH DEPTH SEA DIFFERENCE CORRECT J:ON TOTAL COORDINATES 3698 3698. 3600 0 0 Oo 3798 379,~. 3700 0 0 0,, ........... 3~9'~ 3~g¢,'; .....3'8;00 ............. 0 0 O. 3998 3998,~ 3900 0 0 O. ~098 a098. 4000 0 0 O. 4 lC) B ............................. 4. 19 ,9 '. ............ 4'100 ............0 ......................................... 0 .................................. 0 ° 00 .5 0 · v (.,; O0 $ 0.00 W 00-,5 ................... O;O0'W O0 S 0.00 W O0 $ 0.00 W 0'0"' S ................. 0,00 W O0 5 0,00 4398 4398. 4300 0 0 4598 4598. 4500 0 0 0.00 S goO0 4698 4698. 4600 0 0 0.00 S 0.00 ~'798 ~79B; ....... ~'700 ................. D .................................... 0 ............................................... O.OO'S ............. O.O0 4898 4808. 4800 0 C) 1,45 N 0,54 4998 4998. &gOO 0 0 7.39 N 5.69 .... 51'O'O ~09B"~--'5000 ........... I ............................ I ................................. 22'36'N ............ 14'56 5202 5198, 5100 3 2 40,01N 24,56 5305 5298, 5200 6 3 60,94 N 35,89 .... 5808 ............................. 53q8, ........ 5300 ........ 10 ........................................... 4 ....................................... 85.25 t; ..... 48.83 5513 5498. 5400 15 5 112,13 N 63.58 5619 5598, 5500 20 5 141,79 N 80,57 .... 5726 5698" ...... 5600 ......... 28 ........................................ ~ ....................................... 175.'78"N ........ 100.31' 5R36 5798, 5700 37 9 2.13,85 N 123,12 5946 5890, 5800 48 11 25A°31N 1~7,75 6058 .................... 5gg~, ........ 5900 ............. 60 ................................. 12 ............................... 296.00 N ........ 175.8~ 6168 6098. 6000 70 10 335,96 N 199,~6 6279 6198. 6100 81 11 375.42 N 224.61 6389 6298;---6200 ....... gl ........................ I0 415.32~N ....... 248;I9 6499 6398. 6300 101 10 ~55,22 ~t 271,79 6609 6499, 6400 111 lO ~94,18 N 295.29 -6719 659~, ....... 6500 .......... 120 .............................. 9 ............................. 533'30'N .... 317.89 6~29 669~, 6600 131 11 573,10 t~ 341.51 6939 679~° 6700 Iai 10 613.03 q 365,~0 7050 6898J--~800--152 l[ 653~9 t~ 388';-87 7159 6998. 6900 161 9 692°06 N 411,14 7269 7098, 7000 171 10 730.54 N ~33,74 W ,..} URED DEPTH AND OTHER DATA FOR EVERY EVEN IO0'FEET OF SUB SEA DEPTH· .,.. 25 JUNE 79 '' TRUE ME'AS~R'E'~ ............ V~RTICAL---~U~ ..... M~;¥V~ ................... VERT'ICAL-- ' DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES : 198 198, 100 0 0 0 298 298, 200 '~ 0 0 0 398 398· 300 0 0 0 498 498· 400 0 0 0 5gB 598· 500 0 0 0 698 ............................................ 698'; ........... 600 .............. 0 0 0 798 798, 700 0 0 0 898 898, 800 0 0 0 ..... 998 .......................... 998. ........ 900 ...... = ...... 0 .................................................................. o o · OOS 0,00 W ,00 S 0·00 W .'oo"s .................... O,oo"w ,00 S 0,00 W · 00 S 0,00 W · 00 S ..... 0,00 W !' o00 S 0,00 W · 00 S 0,00 W ,'oo's ...................... o;oo-w ................................................................. 1098 1098, 1000 0 1198 1198· 1100' 0 .... 129'~ ............... 129~'~ 1200 0 1398 1398, 1300 0 1498 1~98. 1400 0 i598 ........................ 1598; ...... 1500 ................ 0 1698 1698. 1600 0 1798 1798, 1700 0 1898 ................... 1898, ............. 1800 ............... 1998 1998· 1900 0 0,00 S 0·00 W 0 0.00 S 0.00 W 0 .................................... O;O0"S .................. 0,00 W 0 0·00 S 0,00 W 0 0·00 S 0,00 W 0 O;'O0-S ................. O~O0--W 0·00 S 0,00 W 0,00 S 0,00 W 0,00 S " 0,00 W OeO0 S 0·00 W 0 0 0 ............................. 0 0 0 2098 2098 2198 ...................... 2198 2298- 2298 2398 2398 2498 2490 2598 2598 2698 2698 2798 2798 2898 2898 2998 2998 3098 ................ 3098 3198 3198 3298 3298 3398 3398 3498 3498 · 2000 · 2100 · 2200 · 2300 · ........... 2400 .......... · 2500 · 2600 0 0 0 0 0 0 0 0 0 '0 .............................. 0 .................................... 0 0 0 0 0 0 0 . 2700 0 · 2800 0 · 2900 0 ; 3000 .......... 0 ................................ * 3100 0 · 3200 0 0 0 0 0 0 .............................. 0 0 0 0 0 '---- 3300 ............ 0 ........................ 0 ........................... 0 · 3400 0 0 0 ]598 3598, 3500 0 o00 S 0·00 W · O0-'S ............. 0,00' W o00 S 0.00 W · 00 S 0.00 W · 00 S 0·00 W · 00 S 0,00 W · 00 S 0.00 W o00 S 0·00 W ,00 S 0·00 W .00 S 0,00 W · 00'5 ....... 0.00 W · 00 S 0,00 W · 00 S 0.00 W , O0 --S ........... O' 00-' W · 00 S 0,00 W 0 0,00 S 0·00 W WEST T B NO I ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER TRUE DOG LEG DR ! F r' V ER T I C A L ............... g'i3~ ........6R"~'PY ........... Y6'$A[:'-'C66Ab'!'N)~'¥ E-S- ...... C-"i~'~' S''U -R-"E ..... $ ............ s EVER X TY ....... $'E C¥'I6~;~--' ANGLE DEPTH SEA DIREC DISTANCE ANGLE DEG/iOOFT DISTANCE D M DEG. D M S 24 0 6926.51 6828,51 N30.OOE 664.59 N 395,28 E 773.26 N 30 44 35 E 1.330 773.23 , 24 ....... 0 ....... 7012.38 69Z4.38 N30.OOE 697.70 N 414,40 E 811.49 N 30 42 29 E 0.000 811.46 ' '24 0 7098.25 7000.25 N31.OOE 730.64 N 433,80 E 849.72 N 30 41 55 E 0.433 849.68 23 30 7184,29 7086,29 N32,00E 762,92 N 453,58 E 887,57 N 30 43 58 E 0.558 887,54 23 45 7270.41 7172,41 N32.00E 794,87 N 473,54 E 925,24 N 30 47 4 E 0.266 925.21 23 0 ....... 7356.'70 ..... 7258.70 N31.OOE 826,66 N 493.03 E 962.53 N 30""48 44'5 .............. 0;'814 962.50 ...... 23 0 7443,23 7345,23 .N31,00E 858,15 N 511,95 E 999.25 N 30 ~9 9 E 0.000 999,23 22 30 7529e91 7431.91 N30,OOE 889.47 N 530,40 E 1035.60 N 30 48 28 E 0.554 1035,58 22"0 ...... 7616.91 ....... 7518.91 ..... NBO.O'OE ....... 920,29"N ...... 548,19 E ........... 1071'19 N-'-30'-~46-"52 E ............ 0.532 ............... 1071.'16 22 0 7704.07 7606,07 N32,OOE '~ 950.47 N 566,33 E llOb.40 N 30 47 17 E 0.797 1106,37 21 0 7791e53 7693,53 N32,00E 979e69 N 584,58 E 1140.85 N 30 49 28 E 1.064 1140,82 21-'15 .... 7'879'21 ...... 7781.21 .... N31.OOE ........ 10'08.58 N ....... 602.28 ..... E ......... 1174.72"N 30 50 38 E .......... 0.300 1174.70 ........ 21 0 7966.89 7868,89 N31,OOE 1037.61 N 21 45 8054,42 7956,42 N32.00E 1066,83 N 21 30 8141.81 B04~.8! ..... N33.00E"' 1096.04 N 22 0 8229.12 8131.12 N32.00E 1125.42 N 674.96 E 1312.30 N 30 57 10 22 0 8316,27 8218e27 N33.00E 1155.12 N 693,88 E 1347,50 N 30 59 36 22 ...... 0 ........ 8403.43 ..... 8305'43 .... N33.00E ...... 118~.65' N ........... 713'06"'E ..... 1382.70"N '31 ...... 2"40 22 0 8490.58 8392e58 N32.00E 1214,35 N 731.98 E 1417.90 N 31 4 50 23 0 8577.~3 8479e43 N33.OOE 1244.68 N 751,31 E 1453,86 N 31 6 56 23 "0" 8663.95"' 8565'95--N33.00E .... 1275'49--N ......... 771.31"E ....... 1490.57 N 31" '9 43 23 0 8750.48 8652.48 N33.00E 1306.29 N 791.31 E 1527.28 N 31 12 22 23 0 8771.65 8673,65 N33.00E 1313.83 N 796.2~ E 1536.26 N 31 13 0 619,73; E 1208,60 N 30 50 54 E 0.266 637,63 E 1242.86 N 30 51 59 E 0.811 .... 656,25 E ..... 1277,49 N 30 54' 38 E' 0.302 1208.58 1242.84 1277.47 0.552 1312.29 0.399 1347.49 0.000 ........ 1382.69 0.399 1417.89 1.076 ~453,86 O.OOQ "1490,57 O.OOO 1527.28 O.OOO 1536.26 ¸,3 HOLE CLOSURE 1536.26 FEET AT N 31 13 0 E .ETION REPORT ITIC RICHFIELD CO TIc-'MuLTX-SHOT--$URvEY ~S OF CURVATURE METHOD OF COHPUTATIONS TED FOR EASTHAN BY F N LINDSEY & ASSOCIATES 25 JUNE 79 '~J' WEST_..TRADI N_G__B_~.y... N~ 1 ..................................................................................................... H DECLINATION 31 BEG EAST '. K B ELEV 98 FT ' ,] 3 ......................................................................... R.[. ¢OR..D._. ALL CALCULATIONS PERFORMED BY I TRUE DRIFT VERTICAL SUB ANGI~E ............ DEPTH ............... SEA ..... D M DOG LEG DRIFT TOTAL COORDINATES C L 0 $ U R E S SEVERITY SECTION DIREC DISTANCE ..... ANGLE ....... DEG/iOOFT ...... DISTANCE ..... DEG. D M $ .... 0 ...... 0 .... 6;65 ...... ~;~'5- N-6';66E .... 6;bo-'s ............. 6T6'6"-~ ............. 0';"00 ..... s ........ 0 .... 0 ........ O--'W ............. 0,600 ...................... 5';"00-~ 0 0 ~800,00 ~702.00 N O.OOE 0.00 S 0.00 W 0.00 S 0 0 0 W 0,000 0.00 2 15 4918.96 4820,96 N50,OOE 2,05 N 0,95 E 2,26 N 25 0 0 g 1,892 2.24 9 .... i5 ........ ~0i2',~3 ........ 49i~"'4~ .... N30"ooE ................... 9'22"N ............ 6,97-E ................ ii.s6"'N'~7 .... 5"~9"E ............... 7.~67 ...................... ii.~o 11 0 5104,97 5006,97 N30,OOE 23,53 N 15,23 E 28,03 N 32 55 16 E 1.862 28,02 12 0 5197,08 5099,08 N29.00E 39,84 N 24.46 E 46.75 N 31 33 2 E 1,065 46,75 1~--~0 .... 5288'~5'7'--5'1'~0",'57 .... N28~'ooE 58"~77-'N ...... 3~'~'7~ E 68~7-'N"-30-35 ..... 18 .... E ........... 2~660 ........................ 16 0 5379,26 5281,26 N28,00E 80,60 N 46,35 E 92,98 N 29 5~ 1 E 1,596 92,95 17 15 5469,32 5371.32 N29,00E 104.24 N 59.18 E 119.87 N 29 35 10 E 1,~3~ 119.82 19"' 0 ...... 5558'66 .... 5460"66 .... N30.ooE ........ 129.69'N ............ 73.58 .... E .......... 149.11N 29 34"' 9 E ........ 1.865 .......... 1~9.05 21 30 56~6.84 5548.84 N~O,OOE 157.86 N 23 45 5733,60 5635e60 N~I,OOE 189.02 N 25" 0 ..... 5819.22 ...... 5721,22 N31eooE 222.27 N 26 15 5903.97 5805,97 N32,00E 256,93 N 26 0 5988,37 5890,37 N32eOOE 292,03 N 25 i5 ........ 6073.12 ..... 5975,'12-="N33.00E 326,32 N ...... 25 0 6158.23 6060,23 N33.00E 359.79 N 214,93 E 419,10 N 30 51 12 E 0.266 419,09 24 45 6243.51 61~5,51 N30,OOE 393,50 N 235,59 E 458.6~ N 30 54 33 E 0.619 458.63 25 0 6328,79 6230.79 N30,OOE 427,74 N 255,36 E 498,17 N 30 50 13 E 0.266 498,16 24 45 641~,07 6316,07 N32,00E 2~ 0 6G99,69 6~01,69 N30,OOE 24'30 6585.39 .... 6487,39--'N30.OOE 25 0 6670,76 6572,76 N31.OOE 25 0 6755.95 6657.95 N31,OOE 25 15 6841.06 6743,0~ N30,OOE 89,8~ E 181,64 N 29 38 47 E 2.660 181,57 108.20 E 217.79 N 29 ~7 17 E 2.~00 217,73 128.18 E 256e58 N 29 ~8 17 E 1.330 256,52 149,~2 E 297,22 N 30 10 49 E 1,34~ 297,17 171,35 E 338.59 N 30 2~ 10 E 0.266 338,56 193.19 .... E ........... 379.22 N 30 37 39 E ....... 0.821 ......... 379e20 537.71 N 30 50 56 E 0.458 537.70 576.50 N 30 51 33 E 0,872 576,49 615.10' N 30'48"18"E -0,532 .......... 615.09 65q.46 a 30 47 12 E 0.565 654,44 461,63 N 275,72 E 494,89 N 295,70 E 528,32 N 315.01 E 562,23 N 334,98 E 596.28 N 355,44 E 630,67 N 375.70 E 694.18 N 30 47 56 E 734,09 N 30 46 58 E 0,000 694.16' '.. o.~29 ................ 7:~;o'? ' ~ r" 1200 VER"ICAL SECTION ATLAI~TIC RICHFIELD COMPANY WEST'rRADING BAY No.I SCALE I"= I000' JUNE 26, 1979 RADIUS OF CURVATURE MAGNETIC MULTI-SHOT 2o00 2400 2800 --- 48o0 5zoo TV D -' 8772' TMD= 9078' ALL DEPTHS SHOWN ARE TVD. HORt~_ONTAL VIEW ATLANTIC RICHFIELD COMPANY WEST TRADING BAY No.I SCALE I"=1000' dUNE 26, 1979 RADIUS OF CURVATURE MAGNE]'IC MULTI-SHOT ALL DEPTHS SHOWN J ARE TVD LOCATED IN THE APPENDIX WFL IPR LOG CALIPER SURVEY VOLAN CURVE DATA ,.,..,.'71~/S TRATIGRAPHIC HIGH RESOLUTION DIPMETER [~ OTHER: Alaska District Post O. ',,~ce Box 360 Anchc, ,e, Alaska 99510 Telephone 907 277 5637 SAblP LE TRANSM I TTAL 'SHIPPED TO: State of Alaska Division of Oil & Gas Conservation 3001 Porcupine Dr. Anchorage, Alaska 99501 A~tn: Mr. Wm. VanAllen DATE: July 3, 1979 OPERATOR: ARCo . NAbIE' SAMPLE TYPE: SAMPLES SENT: dry ditch 300 - 2010 2010- 4050 4050 - 5700 5700 - 6660 6660 - 7380 '738O - 8160 8160 - 8880 8880 -9087 IV. Trading Bay Unit NUMBER OF BOXES- eight' SHIPPED BY: UPON RECEIPT OF THESE SAMPLES PLEASE NOTE ANy DISCREPANCIES AND MAlL A SiCNI!D COPY OF THIS FORM TO: -- ARCO OIL & GAS CO. P. O. BOX 360 ANCHORAGE, ALASKA 99510 ATTN' DICK BROOKS' RECEIVED BY' D,\TI{ ARCO Oil and Gas Cornpan1 is a Division o[ ^!l:lnlic[tichfh. hlCo.;p.,r.y Operator and well name ~O Oil ~d Gas Wes~ Trading Bay ¢1 Location Upper Cook Inlet, Sec. 18 TgN-R13W, 1312' FNL, 516' FEL Shot Recovered 2O 16 Depth 7866L 7864G 772tP 7719P 7708P [--: 7706P 7619L Remarks Description Sandstone: very pebbly with dark gray chert, white qtz, and green fine-grainedvolc.-lithic pebbles altered %o soft sticky green clay. minor chunks of coal; med. to coarse sand (A/A) with sticky wht ashy matrix. No recovery - lost bullets Sandstone: light gray, fine to medium grained, moderate sorting, friable %o moderately firm, subanq subrnd, qtz, chert, some V°lcanic lithic grains, wht soft, sticky matrix. % Oil Oil fluor Show stain Intensity sum dull ~ a]_r fair AR3B-2390 Described by ....... .... ~Nan_cy_G._ Rat ~e ~'~_~ ...................................... Operator and well name ARCO Oil and Gas West Trading Bay ~1 Location Upper Cook Inlet, Sec. 18 TgN-R13W, 1312' FNL, 516' EEL Shot20 lRec°vered Depth 7617G 7615G 7350L 7346G 7342G Rec. 3/4" ---- Description % Oil stain Sandstone: very pebbly, dominant- 1-2% ly dk gray chert pebbles; sand reed to coarse grained, qtz, chert, minor green volc. lithics altered to soft green clays. 16 Oil fluor Show Intensity sum trac~ Fair fair Remarks Described by Nancy G. Rat'Eerman AR3B-2390. ARCO Oil and Ga~"~mpany South Alas .... ~sbict P©s~ Office Box 360 A?~chorage, Aiaska 99510 ~Te~ephone 907 277 5637 June 19, 1979 Mr. Hoyle Hamil ton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Hamilton' Enclosed please find the Sundry Notice explaining the plug and abandon procedure for the West Trading Bay #1 well. This work should start on approximately June 20, 1979. Sincerely, C. R. Knowles District Drilling Superintendent CRK/BDR/slw Attachment cc- WTB #1 ll.A.3 ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany Form 10-403 REV, 1-10-73 Subml t "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) 5. APl NUMERICAL CODE 50-733-20325 6. LEASE DESIGNATION AND SERIAL NO. ADL 18777 7, IF INDIAN, ALLOT1-EE OR TRIBE NAME '~- o,- r-1 ~AS F-1 Exploratory N/A WELLL...I WELL, OTHER 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Atlantic Richfield Company N/A 3. ADDRESS OF OPERATOR 9, WELL NO. P. 0. Box 360, Anchorage, Alaska 99510~ West Trading Bay #1 4. LOCATION OF WELL At su trace 1312'S & 516'W from NE cr Sec 18, T9N-R13W, SM , 13. ELEVATIONS (Show whether DF, RT, GR, etc.) !66' RKB to mud li'ne, w/68' MLLW depth 14. Check Appropriate Box To Indicate Nature of Notice, Re 10. FIELD AND POOL, OR WILDCAT Wildcat 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 8, T9N-RI3W, SM 12. PERMIT NO. 79-8 )orr, or Other Data TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) NOTICE OF INTENTION TO: PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated dat; of starting any proposed work. Due to the absence of hydrocarbons, we propose to plug and abandon the West Trading Bay #1 well in the followi.ng manner' Spot a 400' cement plug, 200' below 13-3/8" shoe and 200' inside the 13-3/8" casing. Cut and pull 13-3/8" @.1120' (2 jts. above the 20" shoe). Run in the hole with open end drill pi'pe, set 200' cement plug ·from 1100' to 1300'. Unlatch 20" OCT mud line suspension hanger @ 230', pull and lay down 20" .csg. RIH, cut and pull 30" conductor @ 185'. RIH with open end drill pipe, lay 50' cement plug from 180' to 230'. The por.tion of the well bore, uncemented, will contain 10.2 ppg mud. Jack down rig, move off locati~on, leaving sea floor free of obstructions. 16. I hereby certify that the foregoing is true and correct TITLEDi stri ct Dri 11 i n9 Superi nten~ _. 6-1q-79 (This space for State office use} CONDITIONS O~ AppROV~/'L.'iF ANY: ARCO Oil and Ge~"~;ompany South Alas, District Post Office Box 360 Anchorage, Aiaska 99510 Telephone 907 277 5637 June 8, 1979 Alaska Oil & Gas Conservation Commission State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Attention' Mr. Hoyle Hamilton, Chairman Gentlemen' Attached is the Monthly Report of Drilling Operations for West Trading Bay #1. It is requested that your office retain the submitted material as confidential. Very truly yours, C. R. Knowles District Drilling Supt. CRK/BDR ARCO Oil and Gas Company is a Division of AllanticRichtieldCompany I'~'V, &- I-?0 STATE C,, ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS O,L,,,~L [] G'',,,~,. [] OTH,' Exploratory. 2. NAME OF OP]~TOR Atlantic Richfield Company 3. AbDRESS OF' OPE~,ATOR P. 0. BOX 360, Anch0ra,qe~ Alaska 995]0 4 LOCATION OF WFJ.,L Surface' ]3]2' FNL & 5]6' FEL, Sec 8, T9N-R]3W, SM SUBMIT IN DUP. LICATE ~ API NUAIERICAL CODE 50-733-20325 LEASE DESiGI'~ATION A%'D SEHIAL NO. ADL 18777 7 IF INDIAR~, ALOTTE, E OR TRIBE NAME ]~/A 8. 'L,~IT FARkI OR LEASE NAME N/A 9 WELL NO West Tradina Bav #1 l0 FLFJ.D A_ND POOL". OR %%~I'LDCAT --fl-~]~C , T.. ti. 5{[ (BO'I'TOM HOLE OBJECT~ Sec 8, T9N-R13W, SM 12 PF2IMIT NO 79-8 13. REPORT TOTAL DEP'I'H AT F2'qD OF MON~'I~-I, CHA.\'GF~ IN HOLE SIZE, CASING A~ CHF~TING JOBS INCLUDING DEPTH SET ~ VOL~ USED, p~OP~TIONS. ~TS ~ ~SULTS FISHING JO~ JL~K IN HO~ AND $IDE-~.ACKED HOLE ~D ~Y O~R SIGNIFIC~T ~G~ ~ ~O~ Co~ITIONS Monthly.....Report of Operations for the Month of May 1979. Spotted rig on location 5/4/79. Jumped divers for sea floor inspection and started precautionary sand bagging. RU and drove 30" 310# x-52 conductor to 271' RKB (105' below mud line). NU and tested diverter system. RIH and drilled 17 1/2" hole to 1242' PU 26" underreamer, underreamed to 1242'. RU and ran 28 jts 20" 133# K-55 w/VerSo "L" connector w/shoe @ 1202' and OCT OBS fluted hanger @ 227' {top). Cemented w/1250 sx "G" followed by 400 sx "G" neat cmt. CIP @ 2320 hrs 5/12/79. Washed out 20" x 30" annulus until clear and filled w/Gel-LNSD pill. Welded on Braden-head and tested w/500 psi. NU BOPE and tested all valves on the choke manifold to 5000 psi. Tested BOPE w/State inspector present. RIH w/17 1/2" bit, tagged cmt @ 1185', drilled shoe and cleaned out and drilled to 1252'. Displaced sea water w/fresh water mud. Ran leak-off test w/13.6 ppg leak off point. Drilled 12 1/4" to 4701. Ran DIL, sonic, FDC-CNL, Long Sonic, MLL, Dipmeter and velocity surveys. Opened 12 1/4" to 17 1/2" hole to 4701'. RU and ran 117 jts 13 3/8" N-80 and K-55 Buttress csg w/shoe @ 4690'. Cemented w/2357 sx "G" followed by 400 sx "G" neat cmt. CIP @ 2315 hr 5/26/79. ND diverter and 20" stack. NU and test 13 5/8" x 10,000 psi BOPE. Drilled out FC and tested csg to 1500 psi. Drilled shoe and 10' of formation to I 4711/_,,12 14 Performed hole @ 5231' leak-off on 6/1/79. test. Formation tested 15.5 ppg. Directionally drilling · , ~~'/w,,,,~, ' .... "~u ....... -1~. I he.by ~ify ~ lo, gong m t~e ~0T[ --~t~o~t ~ t~il form il oil and gas conservation commiffee by the J5~ of the luJc~dJng mon~, ~le~ otherwJla directed, CONFIDENTIAL ARCO Oil and Ga"~'~'ompany South Alas District Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 June l, 1979 Mr. Hoyle Hamilton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Hamilton: Enclosed is the Sundry Notice explaining the 13-3/8" cementing job for West Trading Bay #1 as discussed between you and I on May 30, 1979. Sincerely, / C, R. Knowles District Drilling Superintendent CRK/BDR/vl Attachment File: Upper Cook Inlet ll.A.3. West Trading Bay #1 ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany Form 10-403 ~_.~ Submit "Intentions" in Triplicate RE\(. 1-10.73 & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to d rill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELLL--jOIL n-1 WELLGAS D OTHER Expl oratory NAME OF OPERATOR ARCO 0il and Gas Company 3. ADDRESS OF OPERATOR P. 0. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 1312' S & 516' W from NE cr Sec 18, T9N-R13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 166' RKB to mud line, w/68' MLLW depth 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. AP! NUMERICAL CODE 50-733-20225 6. LEASE DESIGNATION AND SERIAL NO, ADL 18777 7. IF INDIAN, ALLOTTEE OR TRIBE NAME NA 8. UNIT, FARM OR LEASE NAME NA 9. WELL NO. West Trading Bay #1 10, FIELD AND POOL, OR WILDCAT Wildcat 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 8, T9N-RI3W, SM 12. PERMIT NO. 79-8 3ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF L----I PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (other) 13-3/8" cement job (NOTE; Report results of multiple completion on Well Completion or Recompletion Report and Log form,) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Confirming verbal approval from Hoyle Hamilton to C. R. Knowles on 5/30/79, to proceed with the drilling operations as a result of the 13-3/8" csg cmt job as follows: 20" 133# Vetco L csg, shoe @ 1202', OCT 0BS fluted hanger @ 227' Ran 13-3/8" 72# N-80 and 68# K-55 Buttress csg w/shoe @ 4690'. ~emented w/2357 sx "G" cmt followed by 400 sx neat. Lost returns after displacing 460 bbl cmt. Bumped plug, released pressure, float held. CIP @ 2315'hr 5/26/79. The calculated cmt top is @ 1830'. This was done by using the caliper log run on the 12-1/4" hole and extrapolating it to the 17-1/2" hole. NU BOPE, drilled 'out FC and tested 13-3/8" csg to 1500 psi. Drilled shoe and !0' of new formation. Performed leak-off test. Tested formation to 15.5 ppg equivalent. ].6. I hereby certify that the foregoing Is true.and correct SIGNED _ . ..... TITLE DATE (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side Alaska Oil and Gas Conservation Commission Chairman of the Commission/vt Lonmie C. Smith /,' Co~nissioner . Bobby Foster ~ Petroleum InSpector May 30, 1979 Witness BOPE Test on ARCO's West Trading Bay #1 Sec. 8, T9N, R13W, SM Permit # 79-8 ....S.a. tu.rd~ay, May 26,. 1977 -ii departed my home at 11:30 AM for a 12:30 PM showup time for AAI flight 135 departmng Anchorage~at 1:00 PM to Kenai. I arrived at Kenai at 1:30 PM where I rented an AVIS car and drove to Nikiski Dock. I boarded a hel.icopter and was flown to the Borgsten-Dolphin rig where I stood-by for the BOPE test to begin. S__uq~y., May 27~,~.1977 - The BOPE test began with the choke manifold, consisting of nineteen 4" manual valves, two 2" manual valves, two positive chokes and -one Cameron hydraulically operated choke. After completing the test on the choke manifold Mr. McKelvey, ARCO drilling foreman, informed me that due to problems with connecting the two choke line shock hoses and the kill line shock hose the test would be delayed. ~:f~day,::May~28,~.~!97? - The test on the BOPE stack began at 2:00 ~M and a leak was discovered at the Cameron hub clamp between the BOPE stack and the well head. ~e stack had to be removed and the ring gasket replaced. After the ring gasket was replaced the BOPE stack, consisting of two sets of 5" pipe rams, one set of blind .rams and one annular preventer was tested. The two choke lines consisting of one 4" manual valve and one 4" I{CR valve each was tested. The kill line consisted of one 4" manual valve, one HCR valve, and one 4" check valve. _The upper and lower Kelly valves were tested next. All of the BOPE was tested to 5000 psig with the exception of the annular preventer which was tested to 3500 psig. The two floor safety valves, one dart type and one ball valve type were on the floor and in good working order. The accumulator unit was tested by turning off the power to the unit and closing two sets of pipe rams, the annular preventer and opening two HCR valves. The unit pressure of 3000 psig dropped to 1800 psig and stabilized. The power was turned:on and a 250 psig pressure gain was attained in forty-five seconds and complete charge pressure of 3000 psig was attained in three minutes and forty-two seconds. The N2 backup bottle pressures were 1900, 1950, 1900 and 1850 psig. In summary I witnessed the BOPE iest on ARCO's West Trading Bay #1. Satisfactory Type Inspection Yes No Item ( ) Location,General (). ( ) 1. Well Sign (~ ( ) 2. General Housekeeping ( ) ( ) 3. Reserve Pit-( )open( )filled (~" ( ) '4. Rig ( ) Safety Valve Tests ( ) ( ) 5. Surface-No. Wells~ ( ) ( ) 6. Subsurface-No. Wells____ ( ) Well Test Data ( ) ( ) 7. Well Nos. , , , ( ) ( ) 8. Hrs. obser , , , ( ) ( ) 9. BS&W __, ._ ,__, ( ) ( ) lO. Gr. Bbls. , , , ( ) Final Abandonment 11. P&A Marker () (~-- ( ) () ('-t ( ) ka Oil and Gas Conservation Comnl ee Field Inspection Report ~ ,,// Well/Platfm Se'c~., TC/~fL/ r~./._.~/-.d.,~ ,..5 H. x;,; ~~N ..... ~ ....... =' .... Represented by,!'), ame& Number[L!¢~L_:~Xu~_,7~ SatisFactory Type Inspection ' ~ PI' Yes No Item (~Dx'[~O. ,-_ ,es_t_s .~ ~.~. ( 17 Master Hvd. Cont,rol Sys.T~d ps~.q (,~) ( 19 Remote 20 Drillinq spool--~ "outlets 21 Kill Li~e-(~-'C~e~' valve 22 PChoke Flowline:.,(~-~'HCR valve 23 Choke Manifold Ho. valvs!:uz_.flgs./~_~ 24 Chokes-(,-~)R~emote(~)Pos.( )Ad,i. 12. Water well-( )capped( )plugged (~-)'] ( ) 13. Clean-up (~-~' ( ) 14. Pad leveled (..) ( ) 25 ~6 27 28 29 30 31 () () () () () () () () Total inspection observation time Remarks hrs/days Total number eaks and/or equip, failures crS_,]-' Test Plug-(~,)41ellhd~ )cs.a( )none Annular Preventer ~y,~'~',_psio B1 ind Rams ..?_~._~__.~PS~q Pipe Ram$_~_ psig Kelly & Kelly-cock~c'~i'__ _psiq Lower ',<el ! y valve ~(~__ps i q Safety Floor valves-(~. )BV '(~-~'~art Notify in days or when ready___ Alaska Oil and Gas Conservation Commission Hoyle H. Hamilton /~~ Chairman of the C~iss~o~~ Lonnie C. Smith Commisaioner Bobby Foste Petroleum Inspector Hay 15, 1979 Inspection of the Borgsten-Dolphin Self-Elevating Platform Rig on ARCO's West Trading Bay #1 Sec.8, T9N, R13W, SM Permit #79-8 [a[~rdaT,~_},[ay.3~_[~.79 - I departed my home at 5:30 A3I for a 6:30 A>I show-up time for AAI flight 109 departing Anchorage for Kenai at 6:55 ~.I. I arrived in Kenai at 7:30 A}I where I rented an Avis car and drove to Nikiski docks. I boarded a helicopter at i0:00 AM and was flown to the Borgsten-Dolphin where I met Mr. Don McKaffety, ARCO Drilling Foreman. Mr. McKaffety and I made a walk-through inspection of the platform. The mud tanks, pumps and mud mixing system are of a good design and sufficient. This area around the mud system is equipped with H2S gas monitors located at four separate points. These monitors are equipped with individual alarms and the master unit, located in the platform quarters, also has an alarm. I inspected the 20" BOPE, consisting of two ram type preventers and one annular preventer, which will be used to drill the 17 1/2 hole to 4700'(+-), and found it to be in very good shape. The accumulator unit, a Cameron-Payne Unit, did not have an emergency N2 back up system installed, t called this ~o Mr. McKaffety's attention and be contacted the Cameron Representative, who was on the platform, and directed him to correct this matter as soon as possible. The diverter system is a very good design. It can be diverted to the gas buster, to a flare line or to the line venting at the derrick crown. After the rig inspection I met the platform medic, who is also the safety man. He explained to me the safety program that he is starting. Ail personnel will be trained for situations involving H2S gas, fire control and well blow-out control- I talked to Mr. Wayne Callins the Rig Manager, about the time period involved. in moving the rig in an emergency situation. He informed me that it would take approximately 2 1/2 hours to install a safety valve in the drill pipe, hang the drill pipe off iffthe B.O.P.E., make necessary disconnects of the flow line, choke line, kill line and skid the rig into position for mov~ing. He informed me that the platform could be lowered at the rate of one foot per minute and that the rig could be ready to be towed from location in approximately four hours. Inspection of the Borgsten-Dolphin ARCO's West Trading Bay ~1 2 b~y 15, 1979 At 3:DO PM I was picked up at the platfom by helicopter and flown to Nikiski Docks. I drove to Kenai airport and boarded AAI flight 144 departing at 4:00 PM for Anchorage. I arrived in Anchorage at 4:30 P~!. In summary I inspected the Borgsten-Dolphin rig on ARCO's West Trading Bay #1 and found the rig to be in good working order with the exception of the N2 back up syst~ on the accumulator unit. ARCO Oil and Ga., }mpany South Alasko Jistrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Mr. Hoyle Hamilton Chairman Alaska Oil & Gas Conservation Commission State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Hamilton: Enclosed is the Sundry Notice~ for final ~ell surface location of West Trading Bay f~l and commencement of the drilling operation. Please contact me if you have any questions regarding this item. Sincerely, ~ C. R. Knowles District Drilling Superintendent Attachment CRK/slw ARCO Oil and Gas Company is a Division of AllanlicRichfieldCompany Form 10-403 ...... Submit "Intentions" in Triplicate REV. 1-10~73 & "Subsequent Reports" in Duplicate STATE OF ALASKA 0IL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. OIL E~ GAS N WELL WELL [..~J OTHER g~x~p lo rat ion 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage, Alaska 99_510 4. LOCATION OF WELL At surface 1311.7' FNL & 515.8' FEL, Sec 18 - 9N- 13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 166' RKB to Mudline w/68' MLLW Depth. 14. CheCk Appropriate Box To Indicate Nature of Notice, Rel 5. APl NUMERICAL CODE 50-733-20325 6. LEASE DESIGNATION AND SERIAL NO. ADL-18777 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. ~U/NIAT, FARMOR LEASENAME N/A 9. WELL NO. West Trading Bay #1 10. FIELDANDPOOL, OR WILDCAT Wildcat ZL SEC.,T.,R.,M.,(BOTTOM HOLEOBJECTIVE) Sec 8, T9N, R13W, SM 12. PERMIT NO. 79-8 ~ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS (Other) SUBSEQUENT REPORT Of: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT H ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) ~in~l location & commencement _ (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15, DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. As attached, the final location of the subject well is 1311.7' FNL and 515.8' FEL, Sec 18 - 9N - 13W', SM, which is 51' N41-3/4° E from the proposed location. The jack-up drilling unit was accepted on location @ 1245 hrs, 5-4-79. Drove 30" structural casing to 105' below mudline (1271' RKB)and spudded @ 1630 hrs, 5-8-79. t,iAY 0 ,;,4 .... An~nuJaue 16. I hereby certify that the fore'going is true and correct TITLE Di .~tri r_t Drl 11 inS g'llpr _ -. DATE,May g~ ~979 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side Form ! 0-403 -~- Submit "1 ntentions" in Triplicate REV. ]-10-73 & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use thls form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) V~IELLL[~WELLGAS r"'] OTHER Exploration NAME OF OPERATOR Atlantic Richfield Company 3. ADDRF-$5 OF OPERATOR P. O. BOX 360, Anchorage, .Alaska 99510 4. LOCATION OF WELL At surface 1311.7' FNL & 515.8' FEL, Sec 18 - 9N- 13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 166' RKB to Mudline w/68' MLLW Depth. 14. Check Appropriate Box To Indicate Nature of Notice, Re '5. APl NUMERICAL CODE 50-733-20325 6. LEASE DESIGNATION ANDSERIAL NO. ADL-18777 7. IF INDIAN, ALLOTTEE OR TRIBE NAME N/A 8. UNIT, FARM OR LEASE NAME N/A 9. WELL NO. West Trading Bay #1 ]0. FIELD AND POOL, OR WILDCAT Wildcat ]]. SEC.,T., R.,M.,(BOTTOM HOLE OBJECTIVE) Sec 8, T9N, R13W, SM 12. PERMIT NO. 79-8 ~ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF [~ REPAI RING WELL FRACTURE TREATMENTH ALTERING CASING SHOOTING OR AClDIZING ABANDONMENT* (Other) Final. locat, ion& comm..ence~en~ _,, (NOTE; Report results of multiple completion on Well Completion or Recompletlon Report and Log form,) ]5. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and 9ive pertinent dates, including estimated date of ~a~ing any proposed work. As attached, the final location of the subject Well is 1311.7' FNL and 515.8' FEL, Sec 18 - 9N - 13W, SM, which is 51' N41~3/4° E from the proposed location. The jack-up drilling unit was accepted on location @ 1245 hrs, 5-4-79. Drove 30" structural casing to 105' below mudline (271' RKB) and spudded @ 1630 hrs, 5-8-79. I hereby certify that the fora'going is true and correct SIGNED , - C. ~Z. 'Kn~(,~l ~:.~ " TITLE D~.~tri~_t Drilling DATE ~Ry 9, ]979 (This space for State office use) APPROVED BY . CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side Y=2 516 612 X= 203 500. Y=2 51 I 5:53 'X= 203:566 OPERATOR AREA WELL ARCO Y=:2 516 480 X= 208 72.1. 515.8 BERGSTEN DOLPHIN UPPER COOK INLET SECTION 18tT 9 Nt R 15W~S.M. WEST TRADING BAt' SCALE: I"= I000' NOTES: I, Location of well site was accomplished by using trlan- · o II Il gulahon stattons SCREW, "TAD" and "TRADING BAY'~ 2. A! I dimensions and coordinates are in feet, ALASKA STATE PLANE COORDINATES ZONE 4, FEET. Y=?- 515 182 X= 208 176 GEODETIC POSITION LAT, 60°§2'27,87'' LONG, 15 I o 38'i 5,6;? CERIFICATE OF SURVEYOR J HEREBY CERTIFY THAT [ AM PROPERLY REGISTERERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT' THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY SUPERVISION ,AND ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT. SURVEYOR Y: 2 51 i 202 X= 208 602: ."~-~ ' ~ c.-, LOCATION SURVEY FOR WEST TRADING BAY No.I LOCATED IN UPPER COOK INLET ATLANTIC RICHFIELD CO. SURVEYED BY INTERNATIONAL TECHNOLOGY LIMITED AN CHORAGE ~ ALASKA HOUSTON ~ TEXAS ARCO Oil and GasC~ompany South Alask istrict Post Office box 360 Anchorage, Alaska 99510 Telephone 907 265 6515 J. P. Johnson Vice President Ms. Ethel H. Nelson Leasing Manager Department of Natural Resources 323 East 4th Avenue Anchorage, Alaska 99504 Dear Ms. Nelson: April 19, 1979 Atlantic Richfield Company acting as operator for Union Oil and Marathon Oil Company will drill the West Trading Bay #1 well ~F: as a "TIGHT HOLE." We request that you close all your present files on this well and keep in a secured area. Any information concerning drilling data or well information should be dispersed on an extremely limited basis and only to authorized personnel on a need to know basis. Please distribute this letter to all personnel involved. We respectfully request your cooperation in this matter and thank you for your efforts in this matter. Very truly yours~, C. R. Knowles District Drilling Superintendent CRK:slw APR 2 0 1979 DJ~. of Minerals & Energy Mgr. Anchorage, Ak. ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany ARCO Oil and Gar~ 3mpany South A]@sM.~ Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 265 J. P, Johnson Vice President Mr. Hoyle Hamilton, Commissioner Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 9.9501 Dear Mr. Hoyle: April 19, 1979 7'-- A Atlantic Richfield Company acting as operator for Union Oil and Marathon Oil Company will drill the West Trading Bay #1 well as a "TIGHT HOLE." We request that you close all your present files on this well and keep in a secured area. Any information concerning drilling data or well information should be dispersed on an extremely limited basis and only to authorized personnel on a need to know basis. Please distribute this letter to all personnel involved. We respectfully request your cooperation in this matter and thank you for your efforts in this matter. yery truly yours, C. R. Knowles District Drilling Superintendent CRK:slw ARCO Oil and Gas COhmpSn'7 is ¢: F~ivisiori r~f Aih nti-'.;F]i~d:fie!dC,.,ir!:mr~, April 12, 1979 Re= West Trading Bay #1 Atlantic Richfield Company Permit 79-8 Mr. C. R. Knowles ARCO Oil and Gas Company P. O. Box 360 Anchorage, Alaska 99510 Dear Sir: Enclosed is the approved application for permit to drill the above referenced well at a location in Section 8, Township 9N, Range 13W, SM. Well samples, core chips and a mud log are required. A direc- tional survey is required. If available, a tape containing the digitized log information on all logs shall be s%~bmitted for copying except experimental logs, velocity surveys and dipmeter survey s. Many rivers in Alaska and their drainage systems have been classified.as important for the spawning or migration of anad- romous fish. Operations in these areas are subject to AS 16.50.870 and the regulatations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the ~abitat Coordinator's office Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title I8, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. C. R. KnoWl W. Trading Bay #I -2- ~pril 12, 1979 Pursuant to AS 38.40, Local ~ire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to drill. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the commission may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. The. blowout equipment must be tested to 4000 psig. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, ~oyle ~. Hamilton Chairman ~¥ O~D~ O? TH= ~ ~L , Alaska Oil & Gas Conservation Commission Eric 1 o sure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o/encl. Department of Labor; Supervisor, Labor Law Compliance Division w/o encl. At~ar~ficFUchfieldComparw Telephone 907 277 56?/ April 9, 1979 State of Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ATTENTION' Mr. Hoyle Hamilton, Chairman RE' West Trading Bay No. 1 Sundry Notice Dear Mr. Hamilton' Attached please find ARCO Oil and Gas Company, a Division of Atlantic Richfield Company, Sundry Notice and new "Proposed Drilling Location" plat describing the change in surface location for the subject well. Sincerely, C. R. Knowles District Drilling Superintendent CRK/BDR/vl Attachment __ I P,, :'::!; !: :':"'-; 't ' ---I 't-~ (~,~.OL __1.. STAT TEC I STAT I CONFER: 'Form lC~403 _~ Submit "Intentions" in Triplicate REV. 1-10-73 & "Subsequent Reports" in Duplicate STATE OF ALASKA 0IL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) OiLwELLF-I WELLGAS F-~ OTHER Expl oratory 2. NAME OF OPERATOR ARCO 0il and Gas Company a Division of Atlantic Richfield 3. ADDRESS OF OPERATOR P. 0. Box 360, Anchorage, Alaska 99510 4. LOCATION OF ~W_ELL _. At. su'ff a-ce '""-. / 1350' S & 550 E of NE cr Sec 18, T9N-R13W, S~ 13. ELEVATIONS (Show whether DF, RT, GR, etc.) RKB is approximately 120' above MLLW 14. Check Appropriate Box To Indicate Nature of Notice, Re APl NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. ADL 18777 7. IF INDIAN, ALLOTTEE OR TRIBE NAME NA 8. UNIT, FARM OR LEASE NAME NA 9. WELL NO. West Trading Bay No. 1 10. FIELD AND POOL, OR WILDCAT Wildcat 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 8, TgN-R13W, SM 12. PERMIT INO. ~ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF E~ PULL OR ALTER CASING FRACTURE TREAT ~ MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Surface locatian chanae SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING ., SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Prior to locating the "Borgsten Dolphin" at the original surface location, ARCO 0il and Gas contracted Dames & Moore to conduct a "-Pre-dril-ling Site Survey". As a result of this survey it was discovered that the original proposed location was only 15 meters northwest of a pipeline from the Monopod Platform to the Trading Bay onshore facility. To eliminate the possibility of interference with the pipeline, we have moved the proposed sUrface location approximately 750' northwest of the original location See attached "Proposed Drilling Location". 16. ! hereby certify tha~oregolng is true and correct Ani}h~)_ra!~a TITLE ~)~, J~)~'~X'~Z~ ~?/X_~t DATE (This space for State office use) APPROVED BY . CONDITIONS OF APPROVAL, IF ANY: T IT LE DATE See Instructions On Reverse Side Form 1.0-~03 REV. 1-10-73 Submi t "I ntentions" in Triplicate *'Subsequent Reports" in Duplicate ,/ STATE O F ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) I '5. APl NUMERICAL CODE 6. 7. 1.WELLL.jOIL r-1 WELLGAS D OTHER Exploratory 2. NAME OF OPERATOR 8. ARCO 0il and Gas Comp.a.n.y a Division of Atlantic Richfield 3. ADDRESS OF OPERATOR i9, P. 0. Box 360, Anchora.ge, Alaska 99510 4. LOCATION OF WELL At surface 1350' S & 550' E of NE cr Sec 18, TgN-R13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) RKB is approximately 120' above MLLW 14. Check Appropriate Box To Indicate Nature of Notice, Re LEASE DESIGNATION AND SERIAL NO. ADL 18777 IF INDIAN, ALLOTTEE OR TRIBE NAME NA UNIT, FARM OR LEASE NAME NA WELL NO. West Trading Bay No. 1 10. FIELD AND POOL, OR WILDCAT Wildcat 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 8, TgN-R13W, SM ]2. PERMIT )orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ]]~ PULL OR ALTER CASING FRACTURE TREAT ~ MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPA1R WELL CHANGE PLANS (Otherl_~Sllrfaae location change SUBSEQUENT REPORT OF: WATER SHUT-OFF' ~ REPAIRING WELL FRACTURE TREATMENT .=~ ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Prior to locating the "Borgsten Dolphin" at the original surface location, ARCO 0il and Gas contracted Dames & Moore to conduct a ",Pre-dril'lin9 Site SurveY''. As a result of thi's survey it was discovered that the original proposed location was only 15 meters northwest of a pipeline from the Monopod Platform to the Trading Bay onshore facility. To eliminate the .possibility of interference with the pipeline, we have moved the proposed surface locati'on approximately 750' ' northwest of the ori'ginal location. See attached "Proposed Drilling Location". 16. I hereby certify thaUregolng Is true and correct ., TITLE DATE (This space for State office use) APPROVED BY, CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side At~anticRichfieldCompany North AmeriCan Producing Division South Aia; .... District Post Office ~ox 360 Anchorage, Alaska 99510 TeJephone 907 277 5637 April 9, 1979 Oil & Gas Conservation Conntission State of Alaska 3001 Porcupine Drive Anchorage, AK 99501 CC)MM q:'~ ' I ':" ~ ,."_:) . ,j i f::,, C) L 2 .. ?'i-,q~T ¢'.- ,::, L ,,T T?C F!LF: Attention: Mr. Harry Kugler Re: Letter of Designation as the Operator West Trading Bay ~1 Exploratory Well Gentlemen: As per your request, attached are two signed letters from Union Oil Company of California and Marathon Oil Company, designating Atlantic Richfield Company as the operator of the subject well. Sincerely, / C. R. Knowles Ditrict Drilling Superintendent CRK:KUP:jh Attachnmnts At~anticRichfie~dCompany North American Producing Division South Ala~ 3istrict Post Office ~ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 April 2, 1979 Mr. F. G. Nagel Exploration Manager Marathon Oil Company P. O. Box 2380 Anchorage, AK 99510 Dear Fritz: Mr. Harry Kugler with the State Division of Oil and Gas contacted me today and requested signed letters which specifically name Atlantic Richfield Company as operator for the West Trading Bay State #1 well. Mr. Kugler stated that designation of operator is indicated with our letter of February 27, 1979 but due to State regulations he has elected to request a letter clearly stating this point. Please sign below thereby indicating your designation of Atlantic Richfield Company acting as operator for Marathon Oil Company in the drilling of this well, and return a signed copy of this letter to us for processing. Sincerely ,/ /~ C. R. Knowles District Drilling Superintendent CRK:jh Mr. F. ~k_~,Nagel'~ Exploration Manager Marathon Oil Company At~a.ficRichfieldCompany North Amerioan Producing Division South A~a~, District Pos~ Office Sox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 April 2, 1979 Mr. E. F. Griffin Operations Mmnager Union Oil Company of California P. O. Box 6247 Anchorage, AK 99510 __ .__L .......! .... To I Action RECEIVED JPJ ___ VVI-; -- C. R. KNOWLE$ ,,%. Ak. Drlg. Sup. Dear Gene: Mr. ~ Kugler with the State Division of Oil and Gas contacted me today and requested signed letters which specifically name Atlantic Richfield Company as operator for the West Trading Bay State #1 well. Mr. Kugler stated that designation of operator is indicated with our letter of February 27, 1979 but due to State regulations he has elected to request a letter clearly stating this point. Please sign below thereby indicating your designation of Atlantic Richfield Company acting as operator for Union Oil Company of California in the drilling of this well, and return a signed copy of this letter to us for processing. Sincerely, C. R. Knowles District Drilling Superintendent ~ F Griff' ~r~i~s ~a~~ Date AtlanticRichfieidCompany North Arner~"'""~ Producing Division !' South Alaska, District Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 J.W. Hart Operations Manager February 27, 1979 Mr. Eo F. Griffin Union Oil Company of California P. O. Box 6247 Anchorage, AK 99510 Dear Gene- Atlantic Richfield company has submitted an application for Permit to Drill West Trading Bay #1 along with the required Plan of Operation to the State of Alaska. Due to the agreed upon surface location as shown in the attached plat, Union Oil Company, Marathon Oil Company and Atlantic Richfield Company must jointly request an exception to the Department of Natural Resources, Title ll ACC-22.055 regulations dealing with well spacing and distance from the lease line. By copy of this letter, as indicated with our approval below, Atlantic Richfield hereby requests an exception to the above statutes. Please indicate your concurrence with this request for exception by your signature below and return a co. py of this letter to us for processing to the Di'vision of Oil and Gas. SincerelY, .~eWr; tY~st Ma~n~ag~er //:'Da aticRichfieldCompany North American Producing Division South Alasr~'~3istrict Post Office Lox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 J.W. Hart Operations Manager February 27, 1979 Mr. A~ Mechler, Jro Marathon Oil Company P. O. Box 2380 Anchorage, AK 99510 Dear Al- Atlantic Richfield company has submitted an application for Permit to Drill West Trading Bay #1 along with the required Plan 'of Operation to the 'State of Alaska. Due to the agreed upon surface location as shown in the attached plat, Marathon Oil Company, Union Oil Company and Atlantic Richfield Company must jointly request an exception to the Department of Natural Resources, Title Il ACC-22.055 regulations dealing with well spacing and distance from the lease line. By copy of this letter, as indicated with our approval below, Atlantic Richfield hereby reques.ts an exception to the above statutes. Please indicate your concurrence with this request for exception by your signature below and return a copy of this letter to us fOr processing to the Division of Oil and Gas. Si ncerely, Operations Manager fs Attachment F'ri tz G. (J~ge 1 ~J Expl orai~io~ Manager Marathon Oil Company Da'te/ NATI~'R.%L RESO]~R(~ES MINERALS AND ENERGY MANAGEMENT 4TH ~ F£#UE -- ~#C~Og,~G£ 9~5~t February 27, 1979 Atlantic Richfield Company North Alaska District Post Office ]2~Dx 360 Anchorage, Alaska 99510 C.R. District Drilling superintendent Reference: LO 79-13 Thank you for your letter of January 22, 1979. /:4,...~. Lease Operations Permit for Exploratory Test~W~e~ell West Trading Bay Upper Cook Inlet is hereby approved subject to ~'-~0-l-i6~ing -StiPulations: 1. Plans for the d~.~.~ .. water distribution drilling vessel, must be sukmlitted to this Office. IO-J3LH . 0 I . . 7~ Solid waste must be backhauled to an approved disposal site. State air quality regulations must be met. No low level flight (1500 feet or less) is %o be made over Trading Bay State Gam~ Refuge between May 1 and June 15. Prior to drilling, a spill prevention control and countermeasure plan must be sutmtitted for our approval. The area around and. below the fuel storage facilities shall have a dik_ _. e surrounding it with i~le m~mbranes beneath or the fuel storage facilities shall be of double wall construction. A cc~pletion report must be sutmtitted within 15 days upon ter- mination of permit activities. This report shall contain the following information: :~. ; , ~_ ,;' ,~ ne Be Actual rouhes of travel and actual, location of.all c~ <~ depic-k~:t on a USGS '~1~ map. List the vehicles used for any off-mad %ravel %hat my have taken place. ', C. Ail additions to original applica%%on. De Ee Fe Statement of clean up achivihies. Time spent in each campsite. Methods of disposal of 'garbage and other camp debris. Sincerely, Ethel H. Nelson Leasing Manager ~OF L£G LAT. 60° 52'27.17" LO.C. ,~ ~o ~.,6.o3. \ Y=2 515 112 X= 208 ! 54 ~ LAr L ONG. 151 °38~3~69~ X= 208 268 ALASKA STATE PLANE COORDINATES, ZONE 4, FEET. LEG .LOCATIONS DETERMINED MAY 4,1979 FOR BERGSTEN DOLPHIN JACK- UP LEG POSITIONS UPPER'COOK INLET WEST TRADING BAY No.I SECTION 18 ,T9 N,R I$ W, S.M. SURVEYED FOR ATLANTIC EICHFI£LD CO. SURVEYE~ BY INTERNATIONAL TECHNOLOGY LIMITED ANCHORAGE, ALASKA HOUSTON, TEXAS AtlanticRichfieldCompany North Amer .>an Producing Division South Ale District Post Office t~ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 22, 1979 Alaska Oil & Gas Conservation Commission State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 ATTENTION' Mr. Hoyle Hamilton Chairman Gentlemen' ~> RE' Drilling Permit Application for Exploratory Test Well, West Trading Bay #1 Transmitted herewith is an application dated January 22, 1979 filed by Atlantic Richfield Company, requesting a drilling permit for an exploratory wildcat test well to be drilled in Upper Cook Inlet. The location of the subject wildcat is approximately 15 miles northwest of Nikishka in approximately 60 feet of water depth. The attached drilling permit application is being submitted in triplicate and includes all of the pertinent programs that may be necessary for your evaluation and issuance. It is requested that your office retain the submitted application and accompanying programs as confidential until such time as this permit is issued. In the event your office should need additional information in conjunction with this application, please do not hesitate to contact us. Very truly yours, C. R. Knowles District Drilling Supt. vl Attachment Form 10-401 ' SUBMIT IN TR, ATE REV. 1-1-71 (Other instructio,.o on reverse side) la. TYPE OF WORK STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN DRILL ~[ DEEPEN [~] b. TYPE OF WELL OIL GAS F'--I SINGLE MULTIPLE roLL [] WELL t2 OTHER Exploration ruNE [] ZONE 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. O. Box 360, Anchoraqe, AK 99510 API 50-733-20325 6. LEASE DESIGNATION AND SERIAL NO. gD1,-18777 4. LOCATION OF WELL ~ -- /~ !850' c ~w~m ~,~p q~ ~o T9H, ~ra H At proposed ~ttom hoZe l~ation ,-r /~,-~ 200' N & 800' E fr~ ~q Cr, Sec 8, T9N, ~3W, ~.~ ~ ~-q-7~ 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR' POST OFFICE* Approximately 15 miles NW from Nikishka 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME 9.WELL NO. West Trading Bay ~1 10. FIELD AND POOL, OR WILDCAT Wild Cat 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 8, T9Nt R13W, SM 12. 14. BOND INFORMATION: TYPE Statewidesuretyand/orNo. Federal Insurance Co. ~8011-38-40 Amount $100,000.00 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) 200 ft. 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING COMPLETED OR APPLIED FOR, FT. Bottom hol~ is approx. 13300 ' to ~BU K-22 bottom ho] e 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 16. No. OF ACRES IN LEASE 1902 Acres 19. PROPOSED DEPTH 10,000' ~iq3 17. NO,ACRES ASSIGNED TO THIS WELL 20. ROTARY OR CABLE TOOLS Rot~'y 22. APPROX. DATE WORK WILL START Rkq3 is approximately 120' above MT.I~q April 1, 1979 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH Quantity of cement Driven 30" 310 150 ' BEg. NA 26" 20" 133 K-55 1000' BML 1500 SX Class "G" 17-1/2" 13-3/8" 72 N-80 4500' ~ML 3000 SX.Class "G" ]2-1/4" 9-5/8" 47 S-95 9880' BML ~p~x~ 1000 SX C.]a~qs "q" *If needed fez 'orotective or test strinq See Attachment for Supporting Operations, Drilling and BOP Programs. IN ~O~ SPACE DESC~BE PRO~SED PROG~M: If propo~l is to de~pen give data on present productive zone and proposed new productive zone. If p~O~l is to ~ or deepen dkection~y, ~ve pertinent data on sub~face locations and measured and true . verti~ depths. Give blowout preventer pro~am. ~ 24. I hereby ce~ify that~e ~or~oing is True an~orrect sxa~. ~~~t~~ ~,~.. danuary 22. 1979 m~ D~str~ct Dr~ll~nq Supt. (This space for State office use) CONDITIONS OF APPROVAL, IF ANY: SAMPLES AND CORE CHIPS REQUIRED I MUD LOG ~YES [] NO I [~ YES [] NO DIRECTIONAL SURVEY REQUIRED [] NO OTHER REQUIREMENTS: SEE TRANSMITTAL LETTER .3-0-773- z o3 PERMIT NO. 7q'' ~ APPROVAL DATE APPOVED BY ~ - ~~~ TITLE *See Instruction On April 12, 1979 h112/79 DATE _ CONTENTS Page Proposed Drilling Location .............................. ' ...... 1 Geological Prognosis .......................................... 2 Drilling Prognosis ............................................ 2-4 Procedure Summary & Time Schedule ............................. 4 Drilling Vessel ............................................... 5 Minimum Well Control Equipment & Test Procedure ............... 5 Geotechnical Program ............................... ........... 5 Discharges .................................................... 6 Supporting Operations ......................................... 6 Appendix "A" .................................................. 7-10 Appendix "B" .................................................. ll ·. ARCO 7 I TRRDIN9 BAY UNIT I / / / / ! -) UNION-MARATHON 8 B.H.L. yB00" FIJI. UNION- MARATHON -17 ~30g ~ FSL & T 9 N - R 13 N~ SURFROE LOCRTION COORDINRTES ASP ZONE 4 X=20B. 679.36' Y=2.514,630.70' LATITUDE $0"52'22.55~. LONQITUDE 151"38'0S.17' SCRLE: 1 "=20gl0 ' ~EST TRRDING BRY NO. PROPOSED DRILLING LOCRTION UPPER COOK !NLET T 9 N - R 13 N, S.H. RPPLICRTION BY: RTLRNTIC RICHFIELD COHPRNY DRTE: DECEHBER 197B X21158 ARCO ARCO ~./. SURFACE 13543' FNL ~43' FEL 18 UNIT UNION-MARATHON B.H.L. UNION- MARATHON -1 T 9 N - R 13 ~, S.H. SURFACE LOCATION COORDINATES ASP ZONE 4 X=208,140.70' ASP Y=2,S15,116.S4' ASP LATITUDE 60'52'27.21" LONGITUDE 151'38'16.29' SCALE: I "=2000 ' WEST Ti~ING BAY NO. 1 P~OPOSED D~ILLING LOC~TION UPPE~ COOK INLET T 9 N - R 13 N, S.H, ~PLIC~TION BY: A.R.CO. OIL ~ND gAS ~MP~NY DATE: APRIL, 1979 X00639 ARCO OIL & GAS COMPANY Div. of Atlantic Richfield Company West Trading Bay #1 Geological Pro_g_nosis The West Trading Bay prospect is a southwesterly plunging faulted anticlinal nose located downdip from the Monopod feature. It was formed by movement along the Trading Bay fault which separates the Monopod and McArthur River field structures. It is located in the high block and is related to the Monopod structure. Several cross-faults splaying from the Trading Bay fault are present, two of which set up this play and form the trap. As is the case in the Monopod field, a separate oil-water contact also is expected in this trap. There is a crestal shift to the southwest from the deep to shallow structures, probably due to drag on the cross-fault which forms the primary south block of the prospect. A directional hole will be drilled which will test the shallow upper Tyonek sands in the north block, cross the fault at -2,050'- and test the deeper middle and lower Tyonek and Hemlock sands in the south block. Middle Tyonek "E" sands are expected at 4,600' TVD and Hemlock at 7,900' TVD. The well will bottom in Mesozoic Jurassic rocks. Proposed TD is 10,000' TMD (-9,500' sea level) located 200' FSL and 800' FWL, Section 8, T9N-R13W, SM. Surface location is -I~Fa{~-'-FNL-~n~-~{~'--FC-L, Section 18, T9N-R13W, SM. Water depth is about 60 feet MLLW. Drillin9 Prognosis NAME' TD' OBJECTIVE' LOCATION' WATER DEPTH' RIG' ELEVATION- West Trading Bay #1 10,000' RKB This well will be drilled as a straight hole from surface to 4750' KOP. Then directilonally at approximately 25° average angle through the Hemlock, W. est Forelands and 300' to 500' of Jurassic Formation to a total depth of. lO,O00'. Surface' T851~"~FNL-&.--O! FNESec 17, T9N-R13W, SM BHL' 200' FSL & 800' FWL Sec 8, T9N-R13W, SM 60' (.Approx.) S~itable Jack Up. All depths are RKB unless otherwise stated. RKB assumed as 120' above MLLW (2) ESTIMATED DEPTH: MUD PROGRAM: Mud Line (Tertiary) 180 30" Casing Point (Driven) 330 20" Casing Point 1180 13-3/8" Casing Point 4680 9-5/8" Casing Point 10000 Total Depth lO000 NOTE: Casing points and other depths may need to be adjusted after determining exact water depth and air gap. 26" hole to 1200' - Drill using sea water. Clean hole with 50 bbl viscous mud pill every 30' of penetration or more often if required. Fill hole with viscous mud prior to running 20" casing. 12-1/4" hole to 4700' - Drill out of 20" shoe with fresh water low solids gel mud. Control water loss to less than 20 cc. SAMPLES: MUD LOGGING: LOGGING PROGRAM: 17-1/2" hole to 4700' -Open 12-1/4" hole to 17-1/2" using same mud system and controls used to drill 12-1/4" hole. 12-1/4" hole to 10,000' - Drill using a lignosulfonate dispersed mud system. Mud weight will be determined by hole conditions and pore pressure estimates. Main- tain API HT/HP water loss at less than 18cc. Maintain adequate pH to avoid bacterial formation of sour gas. Mud weight is expected to range from 9.0 to ll.5 ppg. Cuttings samples to be collected as instructed by wellsite geologist. From drilling out of 30" casilng shoe to TD. Run 1 2 Interval ll80' to 4700' to 4700' 1 O, 000' Hole Size 12-1/4" 12-1/4" DIL-SP X X BHC/S-GR X X FDC-CNL-GR X X LSS-GR X X MLL X X V61ocity Survey X X Temperature Log * * Dipmeter X X Sidewall cores as needed *As directed by Company geologist and drilling engineer. NOTES: 1. Tape all loqs~. 2. Additional logging runs may be made as required by Company geologist. SURVEYS' CASING PROGRAM' Run a single shot directional survey at 500I intervals, or every bit run of less than 500', whichever is the shorter interval. 30" @ 330' RKB- 150' BML: 310#, l"- wall. 20" @ ll80' RKB - 1000' BML: 133#, K-55 w/Vetco L connectors. 13-3/8" Ia 4680' RKB -4500' BML: 72#, N-80 w/BTC. 9-5/8" @ lO,O00' RKB - 47# S-95 BTC. PROCEDURE SUMMARY & TIME SCHEDULE .Operations 1. Position rig over location, rig up to drill 2. Drive 30" casing to 150' -+ BML and rig up diverter 3. Drill 26" hole to 1200' Z~ RKB 4. Run 20" casing and cement in place. NU BOPE and test 5. Drill 15' of new formation and perform a leak-off test 6. Drill 12-1/4" hole to 4700' +- RKB coring as requi'red 7. Run logs 8. Open 12-1/4" hole to 17-1/2" 9. Run 13-3/8" casing and cement in place. NU BOPE and test 10. Drill 15' of new formation and perform a leak-off test ll. Directionally drill 12-1/4" to TD coring and/or 1.ogging as required by wellsite, geologist 12. Run logs 13 Run & cement 9-5/8" casing, if needed 14. Perform production tests 15. Pl.ug & abandon well, leavi, ng seafloor clean and release rig. Time in Da~s_ 3 1 1 3 1/2 5 1-1/2 4 3 1/2 31 2-1/2 3 9 72 days (4) DRILLING VESSEL A suitable jack-up drilling unit with specifications similar to the "Borgsten Dolphin", owned by Dolphin International, will be used to drill this well. A detailed description of equipments and characteristics of this vessel is attached as Appendix "A". MINIMUM WELL CONTROL EQUIPMENT AND BOP TEST PROCEDURE A. Structural casing, Conductor pipe, Surface casinq~ The structural casing (30") will be driven to 150' - BML. Jetting and/or drilling 36" hole is also considered as a contingency plan if a premature refusal occurs while driving. A 26" hole will be drilled below the 30" casing string to the conductor setting depth. This operation will be carried out with diverter systems only. Before drilling below 20" casing, the BOP equipment will include one annular type preventer and one double ram type preventer rated at 2000 psi WP. Before · drilling below the 'surface casing (13-3/8") the minimum BOP equipment will consist of one annular type preventer rated at 5000 psi WP and at least three sets of ram type preventers rated at a minimum of 5,000 psi WP. (See Appendix "B"). B. .Testing_ All preventers will be tested to 70% worki.ng pressure or 70% of the burst rati.ng of the exposed casi,ng string, whichever is lower. A BOP test will be performed not less-than once a week, after each repai, r operation which requires breaki.ng of a pressure seal and after each well control operations. An unannounced blow out prevention drill will be conducted for each drilli.ng crew at least weekly to assure that the crews are well trained in performi,ng required emergency duties. All these tests and drills will be recorded on the driller's 1.og.- C. Other Equipment An inside blowout preventer ('back-pressure valve) and an essentially full openi,ng drill string safety' valve in open position will be maintained on the rig. floor to fit all pipe in the drill string. An upper kelly cock will be installed below the swivel and a lower kelly cock which can be run through the diverter head will be installed at the bottom of the kelly. GEOTECHNICALPROGRAM Prior to the commencement of drillicng operations, a site survey will be performed on the proposed location for a sufficient' geotechnical evaluation. This geotechnical program will consist of mudline profile survey and sea floor samples using drop cores, which will yield data on sediment wet density, undrained shear strength of the foundation, and grain-size distributions. Such data will be used to thoroughly evaluate soil bearing capacity and the depth of 1.eg penetration with the rig under various operating conditions. The spud-can type footing of this rig has been used many times all over the world. The legs are made of cold temperature steel, and the footing design is much more sophisticated than that of "George Ferris". The geotechnical survey and analysis, however, is our effort at assuming safety of the operation, the public and the environment by forestalling problems such as the incident encountered by the Ferris in 1975. ('5) DISCHARGES The'discharge of drilled cuttings and small quantities of mud will be similar in quality and quantity to typical platform rig operations of the Cook Inlet. Sewages will be treated by the rig's Demco WT-6000-C unit before discharge. An oil-water separator skimming tank will prevent the discharge of oily fluids. No hydrocarbons will normally be used in the mud system. If any is used to treat severe hole problems, it will be collected for proper disposal. All discharges will be in accordance with the National Pollutant Discharge Elimination System (NPDES) and applicable State of Alaska permits, which are currently being applied for. SUPPORT OPERATIONS A. Base Facilities The Rig Tenders Dock which is located at Nikishka, approximately l0 miles north of Kenai and 15 miles SE of proposed location will be used as a main supply point for the drilling materials, fuel and water. A.R.Co. Warehouse in Kenai will store those materials periodically as well as various vendors' facilities in the area. B. Transportations One sea going type supply vessel will be used to transport drilling materials and supplies to the rig. A contract helicopter will be used to transport personnel, foodstuffs and light weight equipments between the rig and Nikishka. Personnel, equipment, and supplies may also be transported between Anchorage and Kenai by both chartered and commercial air carriers. C. Communications Primary communications between the rig and Anchor. age will be via micro wave radio telephone. The communications network to support the logistic operations will also consist of ARCO Kenai office, Rig Tenders Dock, helicopter, and workboats via VHF radio. (6) Appendix "A" BORGSTEN DOLPHIN SELF-ELEVATING DRILLING PLATFORM/300' WATER DEPTH CONSTRUCTION: Levingston Class 111 Design Builder--Mitsui Shipbuilding & Engineering Co. Delivery--December 1975 REGISTRY: Norway (NSC & NMD Approvals) CLAssIFICATION: ABS,-~A1 Self-Elevating Drilling Unit JACKING SYSTEM: Type--Opposed Rack & Pinion, Electrical National Supply Div., ARMCO Steel Corp. Speed--60 Ft Per Hour QUARTERS: 80 Men, Central Heating and Air-Conditioning HELIDECK: Sikorsky S-61 Loading DIMENSIONS: STORAGE CAPACITY: Hull Length Beam Depth Drilling Slot Width Length Normal Hull Draft Leg Type & No. Size Length Overall Footing Size Drilling Pattern Spacing, Longitudinal Transverse --208 Ft --178 Ft -- 22 Ft -- 50 Ft -- 5O Ft -- 12Ft --Square Truss, 3 --22' x 22' --418' --48' Diam. --9 Wells --8 Ft Max. --8 Ft Max. Maximum Variable Load --1500 Tons Liquid Mud (4 Pits). --1560 Bbls Bulk Mud & Cement --6780 Cu. Ft Sack Materials --5000 Sacks Fuel Oil --1850 Bbls Drill Water --4700 Bbls Potable Water --1250 Bbls POWER PLANT 3--EMD Model MD16E8 Diesel Generator Sets, Engine rated 2200 BHP, AC Generator A-20-6 rated 1500 KW, 6O0 V 1--Ross Hill Controls Corp. AC/DC Thyristor System, including; 3--Generator Control Switchboards 4--Model 1600 SCR Cubicles (each to drive 2--D79 DC Motors) 1--Caterpillar Model D-379B Marine Electric Set for Emergency/Standby -Service, rated 400 KW, 460 V AC DRILLING EQUIPMENT Derrick Crown Block Drawworks Rotary C-E 147' Model 20RD, Bolted, Dynamic Derrick 1,400,000-1b. APl Capacity; with standard accessories and Traveling Block Guide, S&R Tool Casing Stabbing Boom, and Derrickman's Air Tugger C-E Model'RA-60-7, rated 650 Tons C-E Model C-2 Type Il driven by two EMD D79 800 HP DC Motors, with Lebus 1%" drum grooving, Two-Speed Transmission, Heavy Duty Catheads, Sandreel, Elmagco 6032 Brake, Crown-O-Matic, Swaco Control, C-E and Ross Hill Driller's Consoles C-E T-3750 Table with 37V2" opening, Two-Speed Independent Drive powered by EMD D79 800 HP DC Motor Traveling Equipment Rig Floor Equipment C-E RA-60-6H-5500 Hook Block, rated 500 Tons C-E LB-650 Swivel, rated 650 Tons Drilco 6" x 40' Kellys (2) and erasco Upper and Lower Kelly Valves Varco Power Sub, Series 6500 tteavy Duty BJ Elevator Links & Pipe/Collar/Casing Elevators Varco 500-Ton Casing Elevators/Tools Ideco Mouse-O-matic Automatic Mousehole Tongs Varco Model 10 Air-Powered Spinning Wrench Drilco EZY-TORQ Unit I!, Hydraulic Drill Collar Tool Lamb Model 16,000 Hydraulic Tongs BJ Type DB Rotary Tongs, 3Y~" to 17" Web Wilson Type AAX Casing Rotary Tongs, to 21" Varco Type MPCH Master-Casing Bushing, 14inge'd, Pin Drive with Split Insert Bowls and Type CB Split Casing Bushing for casing to 20" Varco Type 27HDP Roller Kelly Bushing Varco DP, DC, and Casing Slips and Safety Clamps Cedco Wireline Unit, 25 HP, 25,000' el .092" line King Circulating t lead & Wireline Stripper Okeh Mud Saver Bucket I-R Air t~oisls, 1 --ODR 100A24, 1--ODR40A15 Drill String & Downhole Tools Substructure & Equipment Drilling Instrumentation Mud Circulating System Mud Trip Tank, capac 22V~ bbls Delmag Model D-30 Die'sel Casing Hammer with lead and accessories for 16" through 40" 5" Grade G Drill Pipe, 18,000', plus Pup Joints 5" Hevi-Wate Drill Pipe, 30 Jts Drill Collars, NO-WALL-STICK, Hardbanded, 9V2", 8", 6'/2" Baker Model G Full Flow Float Valves Gray X-Hole Float Valve & Release Tool Subs--Bit, Lift, Kelly Saver, Junk Basket, and Crossover Christensen 6V,"x3" Marine Series Core Barrel Bowen Fishing Tools for 81/~'' to 26" hole size Lower Skid Base, 30'x50', with cellar deck having work area and BOP storage stumps, longitudinal travel provided by hydraulic cylinders and claw bases Upper Skid/Substructure, 30'x30', with .hydraulic cylinders and claw bases for transverse skidding 8' each side of center BOP Handling System with two 25-Ton Trolleys, two Hydraulic Hoisting Winches, two I-R Air Hoists for trolley travel, winch/hoist Control Stand Utility Air Hoists, four I-R Model ODR40A15 70 cu. ft Air Receiver for rig service C~E Drawworks Console Ross Hill SCR Driller's Console . Auxiliary Driller's Console with running lights/remote controls: DC Motor Blower Lights Drawworks Oiler Low Pressure Light Mud Charging Pump Lights Mud Pump Chain Lube & Liner Wash Lights Shale Shaker Motor Lights Brake Cooling Water Temp/Level Lights Brake Cooling Pump Lights & Controls Hydraulic Power Unit Lights & Controls Desilter/Desander Pump Lights & Controls TOtco Instrumentation Console displaying: M-D Type E Weight Indicator Rotary RPM & Torque Tong Torque (EZY~TORQ Unit) Swaco Driller Control Pump Pressure (2) Pump Stroke Rate & Counter Pit Level Indicator Mud Flow Indicator Mud Gain/Loss Indicator 'l-otco 6-Pen Drilling Recorder, Model 62-A Totco 2-Pen Drilling Recorder, Model DR2W Totco Mud Flow Sensor/Recorder Unit No. F Totco Vertical Pitometer/Recorder Unit No. L-4 'fotco Deviation Recorder Unit No. 6, Double 0o-8° Two C-E Model FA-1600 7V2"x12" Triplex Mud Pumps, each chain driven by two EMD D79MB 800 HP DC Motors, with suction dosurger, pulsation dampener, (8) .d Cameron reset relief valv(; One C-E Model F-350 6:¼"x7" Triplex Shear Mud Pump chain driven by a GM12V71N radiator-cooled diesel engine, with suction d(:surger, pulsation dampener, and Cameron reset relief valve Three Mission 5x6 Centrifugal Charging Pumps with 12" impellers, each driven by one 40 HP 1200 RPM AC motor. Dual Mud Standpipe & Manifold, 5~, ,~" 5000 PSI WP, with Cameron Flex-Seal Valves, and M-D Pressure Gauges Three NRP Powerflex Rotary Hoses, 3VWx60', 10,000 PSI Test MudConditionin9 CentrifugesModeICRVS-11 Dual High & Mixing Speed Shale Shaker Weico Model 5200 Degasser Pioneer Model S3-12 Desander Pioneer Model T16-4 Desilter Two Mission 6x8 Centrifugal Desilter/Desander Pumps with 13~/~'' impellers, each driven by one 75 HP 1200 RPM AC motor Shaker Mud Tank, 250-bbl, with sand trap and three compartments Two Mission 6x8 Centrifugal Mud Mixing Pumps with 13%" impellers, each driven by one 75 HP 1200 RPM AC motor Demco No. 612B Mud Hopper and No. 612 Sack Cutting Hopper Philadelphia Mud Mixers, four Model Petro-10 with 25 HP AC motors for mud pits and two Model MT-02 with 5 14P AC _motors for slugging tanks Bulk Material Six Halliburton Storage Tanks, 12' D x 15' System High, 1130 cu. ft each, with Hi-Level Indicators, Valves and Fittings Two Halliburton Surge Tanks, 5' D, 70 cu. ft each, with Valves, Fittings and Dust Boot Cementing Halliburton Twin HT-400 driven by two GM Unit 8V71 Diesel Engines, radiator-cooled, with Halliburton five-valve "1-1" Manifold Halliburton Sack Cutting Hopper Logging Foundation and service connections for Units Electrical Well Logging Unit Foundation and service connections for ' ' Mud Logger Unit · Well Control 21%" BOP Stack Equipment Rucker Shaffer Spherical Preventer, 2000 PSI WP, 21%" Bore, with clamp hub bottom and studded top Cameron Type U Dbl, 2000 PSI WP, 21%" Bore, with clamp hub top and bottom, shear rams and 5" rams, and four 3' "clamp hub outlets /16 13%" BOP Stack Rucker Shaffer Spherical Preventer, 5000 PSI WP, 13%" Bore, with clamp hub bottom and studded top Cameron Type U Sgl, 10,000 PSI WP, 13%" Bore, with clamp hub top and bottom, blind rams, and two clamp hub outlets Cameron Type U Dbl, 10,000 PSI WP, 13%" Bore, with clamp hub top and bottom, 9%" rams and 5" rams, and tour 3' ,~" clamp hub outlets Additional set 5" tarns and 7" rams Kill and ChokeAssen,. j,61ineswith Cameron Type F 3t,;~" Manual and Hydraulic Valves, Cameron Check Valves and Pressure Gauges Cameron Payne Accumulator Unit, 270-gallon 3000 PSI WP, combination air and electric motor, automatic, with Payne six-station Fluid Control Manifold Two Payne Graphic Remote BOP Control Panels, each six-station, pneumatic operation Cameron Choke Manifold with 3'/,~" Type F Valves, three Positive Chokes and provision for one Adjustable Choke Mud-Gas Separator Regan Type KFDS Diverter Assembly with Fixed Support Housing, Telescoping Joint with hub clamp/flange adapter to fit each BOP stack, dual flow lines with pneumatic operated 12" sliding blind valves Diverter Control Panel for operation of all diverter functions and flow line valves Cameron Model DP1092C 10,000 PSI Test Pump, air-driven, for supplyin, g test fluid to BOP stacks, choke/kill lines, and choke manifold HULL EQUIPMENT Central Air System Cold Start Air System Water Makers Hydraulic Power Unit Brake Cooling Water System Pollution Control 2--Worthington Rollair Model 125/125 Rotary Screw Compressors, each rated 476 SCFM at t25 PSIG and driven by one 150 HP AC motor, with sequence- alternator control unit, and aftercooler 2~Worthington Model 120A Refrigerated Air Dryers, each' rated 600 CFM at 125 PSIG, packaged and piped with 125/40 PSIG regulator, Centrifix RW5" separator, and safety relief valve 1--Air Receiver, 53 cu. ft, 150 PSIG WP 1--Worthington Model ED ComPressor, rated 20 CFM at 250 PSIG, driven by a Lister Model SR2 air-cooled diesel engine --Air Receiver, -32 cu. ft, 400 PSI.G WP 2--A~iua-Chem Model S300SPEC-E Vapor Compression Distilling Units, each rated 330 GPH output, with electric motor driven compressor --Aquafine Model CSL-24 Ultraviolet Sterilizer 1--Lamb Model LP364-2 Dual Tandem Unit, rated 3000 PSI, driven by two 60 HP AC Motors, complete with reservoir, valves and controls. FoFsupplyin9 hydraulic fluid to power tongs, EZY-TORQ, casing stabbing boom, BOP handling winches, and substructure skidding jacks 1--Specific Offshore Model C2606 Unit with two 2x3 Centrifugal Pumps driven by '40 HP AC motors, two heat exchangers, Iow level switch and temperature' sensor, 30-bbl tank 1--Demco Model WT-6000-C Waste Treatment Unit 1--220-bbl Bil9e Holding Tank 1--660-bbl Skimming Tank 1--35-bbl Dirty Oil Tank Service Pumps Tank/Draft Gauging System Welding System Cranes & Deck Outfit Safety & Lifesaving Radio & Communications ,raps and manifolding tot wasle fluid control 3--Raw Water Pumps, each rated 1200 GPM at 126' total head and driven by a 50 HP AC motor, 12" 3-stage vertical turbine unit with 83' column assembly and 8" discharge head 1--Potable Water Pressure Set with two 5 HP AC motor-driven vertical pumps each rated 70 GPM at 70 PSIG, and one 200-gallon pr.essure tank with .start/stop pressure switches and gauge 1--Sanitary Water Pressure Set, dual pump unit, each rated 70 GPM at 70 PSIG, same as potable water set 2--Drill Water Pumps 2--Fire Pumps 2--Bilge & Ballast Pumps 2--Fuel Oil Transfer Pumps 1--Dirty Oil Transfer Pump Electrical Level Gauges in all water and fuel hull tanks Electrical Barge Draft Gauges (3) Central Display Panel for tank level and draft Ce'ntral System with fixed wiring and outlet receptacles for portable welding leads, two DC electric machines each rated '40O A 2--LeTourneAu PCM-80AS Revolver Cranes, AC & DC power, 100' boom, rated 25 tons at 30' radius 3--Le'rournea'u W-1500-TS Mooring Winches, AC motor driven, two-speed, with 1V~" rope, rated 50,000-IL line pull and 130,000-1b brake capacity 3--8.000-1b State-Type Anchors with crown pendants and buoys 4--Heavy Duty Smit-Type Quick-Release Towing Pads 1--Tow Bridle Recovery Winch Bollards, Cleats & Chocks to meet regulatory body requirements 3--Hand Winches to handle leg jetting hoses Two Lifeboats and one Rescue Boat in compliance with regulatory bodies Life Rings & Life Jackets in compliance with regulatory bodies Combustible and Toxic Gas Detecting System including: 14 Sieger Gasalarm combustible gas sensors 4 Bullard H,S sensors Central Display/Alarm Panel Fire Detection System Fire Fighting Equipment Remote Emergency Shutdown of blower fans and fuel transfer pumps Marine lights, shapes, signals and aircraft obstruction lights in compliance with regulatory bodies 400 W SSB Transmitters &. Receivers FM/VHF Radiolelephone AM/VHF Radiotelepl~one VHF Emergency Transceivers & Beacons Portable Lifeboat Radios Public Addresser System Intercom Telephone System BO. RGSTEN DOLPHIN SELF-ELEVATING DRILLING PLATFORM 300' WATER DEPTH D [.':._] i I ~ ....... 50' 8" ........ 208' ........................................... ~' (~o) Appendix "B" · I Regan ~ KFDS Diverter 12" Diverte~ Line RKB Return Flow Line Legend Telescopic 1. Cameron "U" Single 5000# WP 2.. Hydraulic Remote 3. Check valve lO,O00# WP 4. Gate Valve 5. Cameron "U" Double 5000# WP 6.' Cameron "U" Double 2000# WP 7. Meter - 10,000# WP ker-Shafer Casing Head< I 20" 2000 psil I I I I BOP I I ~ ,~ I Surface Hole Stack - 30" Conductor '20" Casing --- 13-3/8" Casing 9-5/8" Casing BorgsSen Dolphin BOP Schematic (Not to scale) (ll) ARCO OIL & GAS COMPANY Div. of Atlantic Richfield Company West Trading Bay #1 Geological Prognosis The West Trading Bay prospect is a southwesterly plunging faulted anticlinal nose located downdip from the Monopod feature. It was formed by movement along the Trading Bay fault which separates the Monopod and McArthur River field structures. It is located in the high block and is related to the Monopod structure. Several cross-faults splaying from the Trading Bay fault are present, two of which set up this play and form the trap. As is the case in the Monopod field, a separate oil-water contact also is expected in this trap. There is a crestal shift to the southwest from the deep to shallow structures, probably due to drag on the cross-fault which forms the primary south block of the prospect. A directional hole will be drilled which will test the shallow upper Tyonek sands in the north block, cross the fault at -2,050'- and test the deeper middle and lower Tyonek and Hemlock sands in the south block. Middle Tyonek "E" sands are expected at 4,600' TVD and Hemlock at 7,900' TVD. The well will bottom in Mesozoic Jurassic rocks. Proposed TD is 10,000' THD (-9,500' sea level) located 200' FSL~nd 800' FWL, Section 8, T~N-R13W, SM Surface location is~E~eF~C-~-F~,, Section 18, T9N-R13~J, SM. Water depth is about 60 feet MLLW. Drilling .Prognosis NAME' TD' OBJECTIVE' LOCATION' WATER DEPTH: RIG- ELEVATION' West Trading Bay #1 / "i~ ~'-"' ''! >' ""' 10,000' RKB ... , This well will be drilled as a straight hole from surface to 4750' KOP. Then directilonally at approximately 25° average angle through the Hemlock, West Forelands and 300' to 500' of Jurassic Formation to a total depth of 10,000'. ,,~..~' [,,,., ' ~ 2 Surface ~%50~...EINb-&--O ...... ~.WL--$ec.-4-7, T9N R1BW, SM BHL: 200' FSL & 800' FWL Sec 8, T9N-RI3W, SM 60' (.Approx.) Suitable Jack Up. All de~ths are R. KB unless otherwise stated. RKB assumed as 120' above MLLW (2) ESTIMATED DEPTH: MUD PROGRAM: SAMPLES: MUD LOGGING: LOGGING PROGRAM: Mud Line (Tertiary) 30" Casing Point (Driven) 20" Casing Point 13-3/8" Casing Point 9-5/8" Casing Point Total Depth 180 330 1180 4680 lO000 10000 NOTE: Casing points and other depths may need to be adjusted after determining exact water depth and air gap. 26" hole to 1200' - Drill using sea water. Clean hole with 50 bbl viscous mud pill every 30' of penetration or more often if required. Fill hole with viscous mud prior to running 20" casing. 12-1/4" hole to 4700' - Drill out of 20" shoe with fresh water low solids gel mud. Control water loss to less than 20 cc. 17-1/2" hole to 4700' -Open 12-1/4" hole to 17-1/2" using same mud system and controls used to drill 12-1/4" hole. 12-1/4" hole to 10,000' - Drill using a lignosulfonate dispersed mud system. Mud weight will be determined by hole conditions and pore pressure estimates. Main- tain API HT/HP water loss at less than 18cc. Maintain adequate pH to avoid bacterial formation of sour gas. Mud weight is expected to ra~lge from 9.0 to ll.5 ppg. Cuttings samples to be collected as instructed by wellsite geologist. From drilling out of 30" casilng shoe to TD. Run 1 2 Interval llSO' to 4700' to 4700' lO,O00' Hole Size 12-1/4" 12-1/4" DIL-SP X X BHC/S-GR X X FDC-CNL-GR X X LSS-GR X X MLL X X Velocity Survey X X Temperature Log * * Di pmeter X X Sidewall cores as needed *As directed by Company geologilst and drilling engineer. NOTES: I. Tape all logs. 2. Additional logging runs may be made as required by Company geologist. SURVEYS' CASING PROGRAM' Run a single shot directional survey at 500' interVals, or every bit run of less than 500', whichever is the shorter interval. 30" @ 330' RKB - 150' BML' 310#, l" - wall. 20" @ 1180' RKB - 1000' BML: 133#, K-55 w/Vetco L connectors. 13-3/8" @ 4680' RKB -4500' BML: 72#, N-80 w/BTC. 9-5/8" @ 10,000' RKB - 47# S-95 BTC. PROCEDURE SUMMARY & TIME SCHEDULE Operations 1. Position rig over location, rig up to drill 2. Drive 30" casing to 150' ± BML and rig up diverter 3. Drill 26" hole to 1200' ~ RKB 4. Run 20" casing and cement in place. NU BOPE and test 5. Drill 15' of new formation and perform a leak-off test 6. Drill 12-1/4" hole to 4700' ~ RKB coring as required 7. Run logs 8. Open 12-1/4" hole to 17-1/2" 9. Run 13-3/8" casing and cement in place. NU BOPE and test 10. Drill 15' of new formation and perform a leak-off test 11 Directionally drill 12'1/4" to TD cori.ng and/or logging as required by wellSite geologist . , 12. Run logs 13. Run & cement 9-5/8" casing if needed 14. Perform production tests 15. Plug & abandon well, leavi.ng seafloor clean and release rig. Time in D~ays 3 1 1 3 1/2 5 1-1/2 4 3 1/2 31 2-1/2 3 9 72 days (4) DRILLING VESSEL A suitable jack-up drilling unit with specifications similar to the "Borgsten Dolphin", owned by Dolphin International, will be used to drill this well. A detailed description of equipments and characteristics of this vessel is attached as Appendix "A". MINIMUM WELL CONTROL EQUIPMENT AND BOP TEST PROCEDURE A. Structural casing, Conductor pipe, Surface casings The structural casing (30") will be driven to 150' - BML. Jetting and/or drilling 36" hole is also considered as a contingency plan if a premature refusal occurs while driving. A 26" hole will be drilled below the 30" casing string to the conductor setting depth. This operation will be carried out with diverter systems only. Before drilling below 20" casing, the BOP equipment will include one annular type preventer and one double ram type preventer rated at 2000 psi WP. Before drilling below the surface casing (13-3/8") the minimum BOP equipment will consist of .one annular type preventer rated at 5000 psi WP and at least three sets of ram type preventers rated at a minimum of 5,000 psi WP. (See Appendix "B"). B. Testing All ~reventers will be tested to 70% worki,ng pressure or 70% of the burst rati.~g of the exposed casi,ng stri. ng, whichever is lower. A BOP test will be performed not !ess than once a week, after each repai, r operation which requires breaking of a pressure seal and after each well control operations. An unannounced blow out prevention drill will be conducted for each drilling crew at least weekly to assure that the crews are well trained in perfo'rmi.ng required emergency duties. All these tests and drills will be recorded on the driller's 1.og. C. Other Equipment An inside blowout preventer (back-pressure valve) and an essentially full opening drill string safety valve i'n open position will be maintained on the rig floor to fit all pipe in the drill string. An upper kelly cock will 'be installed below the swivel and a lower "kelly cock which can be run through the 'diverter head will be installed at the bottom of the kelly. GEOTECHN I CAL 'PROGRAM Prior to the commencement of drilling operations, a site survey will be performed on the proposed location 'for a sufficient geotechnical evaluation. This geotechnical program will consist of mudline profile survey and sea. floo'r samples using 'drop cores, which will yield data on sediment wet density, Undrained shear strength of the foundation, and grain-size distributions. Such data will be used to thoroughly evaluate soil bearing capacity and the depth of leg penetration with ~he rig under various operating conditions. The spud-can type footing of this rig has been used many times all over the world. The legs are made of cold temperature steel, and the footing design is much more 'sophisticated than that of "George Ferris". The geotechnical survey and analysis, however, is our effort at assuming safety of the operation, the public and the environment by forestalling problems such as the incident encountered by the Ferris in 1975. (5) DISCHARGES The discharge of drilled cuttings and small quantities of mud will be similar in quality and quantity to typical platform rig operations of the Cook Inlet. Sewages will be treated by the rig's Demco WT'6000-C unit before discharge. An oil-water separator skimming tank will prevent the discharge of oily fluids. No hydrocarbons will normally be used in the mud system. If any is used to treat severe hole problems, it will be collected for proper disposal. All discharges will be in accordance with the National Pollutant Discharge Elimination System (NPDES) and applicable State of Alaska permits, which are currently being applied for. SUPPORT OPERATIONS A. Base Facilities The Rig Tenders Dock which is located at Nikishka, approximately l0 miles north of Kenai and 15 miles SE of proposed location will be used as a main supply point for the drilling materials, fuel and water. A.R.Co. Warehouse in Kenai will store those materials periodically as well as various vendors' facilities in the area. B. Transportations One sea going type supply vessel will be used to transport drilling materials and supplies to the rig. A contract helicopter will be used to transport personnel, foodstuffs and light weight equipments between the rig and Nikishka. Personnel, equipment, and supplies may also be transported between Anchorage and Kenai by both chartered and commercial air carriers. C. Communications Primary communications between the nig and Anchorage will be via micro wave radio telephone. The communications network to support the logistic operations will also consist of ARCO Kenai office, Rig Tenders Dock, helicopter, and workboats via VHF radio. (6) Appendix "A" BORGSTEN DOLPHIN SELF-ELEVATING DRILLING PLATFORM/300' WATER DEPTFI CONSTRUCTION: REGISTRY: CLASSIFICATION: JACKING SYSTEM: QUARTERS: HELIDECK: Levingston Class 111 Design Builder--Mitsui Shipbuilding & Engineering Co. Delivery--December 1975 Norway (NSC &NMD Approvals) ABS,-~A1 Self-Elevating Drilling Unit Type--Opposed Rack & Pinion, Electrical National Supply Div., ARMCO Steel Corp. Speed--60 Ft Per Hour 80 Men, Central Heating and Air-Conditioning Sikorsky S-61 Loading DIMENSIONS: STORAGE CAPACITY: Hull Length --208 Ft Beam --178 Ft Depth -- 22 Ft Drilling Slot Width -- 50 Ft Length -- 50 Fl Normal Hull Draft -- 12FI Leg Type & No. --Square Truss, 3 Size --22' x 22' Length Overall --418' Footing Size --48' Diam. Drilling Pattern --9 Wells Spacing, Longitudinal --8FtMax. Transverse --8 Fl Max. Maximum Variable Load --1500 Tons Liquid Mud (4 Pits). --1560 Bbls Bulk Mud & Cement --6.780 Cu. Ft Sack Materials --5000 Sacks Fuel Oil --1850 Bbls Drill Water --4700 BI)Is Potable Water --1250 Bbls POWER PLANT 3--EMD Model MD16E8 Diesel Generator Sets, Engine rated 2200 BHP, AC Generator A-20-6 rated 1500 KW, 600 V 1--Ross Hill Controls Corp. AC/DC Thyristor System, including; 3--Generator Control Switchboards 4--Model 1600 SCR Cubicles (each to drive 2--D79 DC Motors) 1--Caterpillar Model D-379B Marine Electric Set for Emergency/Standby Service, rated 400 KW, 460 V AC DRILLIN(3 EQUIPMENT Derrick C-E 147' Model 20RD, Bolted, Dynamic Derrick 1,400,000-1b. APl Capacity; with standard accessories and Traveling Block Guide, S&R Tool Casing Stabbing Boom, and Derrickman's Air Tugger C-E Model'RA-60-7, rated 650 Tons C-E Model C-2 Type 11 driven by two EMD D79 800 HP DC Motors, with Lebus 1%" drum grooving, Two-Speed Transmission, Heavy Duty Catheads, Sandreel, Elmagco 6032 Brake, Crown-O-Matic, Swaco Control, C-E and Ross Hill Driller's Consoles Rotary C-E T-3750 Table with 37~/2'' opening, Two-Speed Independent Drive powered by EMD D79 800 tip DC Motor Crown Block Drawworks Traveling Equipment Rig Floor Equipment C~E RA-60-6H-5500 Hook Block, rated 500 Tons C-E LB-650 Swivel, rated 650 Tons Drilco 6" x 40' Kellys (2) and Omsco Upper and Lower Kelly Valves Varco Power Sub, Series 6500 Heavy Duty BJ Elevator Link's & Pipe/Collar/Casing Elevators Varco 500-Ton Casing Elevators/Tools Ideco Mouse-O-matic Automatic Mousehole Tongs Varco Model 10 Air-Powered Spinning Wrench Drilco EZY-TORQ Unit II, Hydraulic Drill Collar Tool Lamb Model 16,000 Hydraulic Tongs BJ Type DB Rotary Tongs, 3F~" to 17" Web Wilson Type AAX Casing Rotary Tongs, to 21" Varco Type MPCH Master-Casing Bushing, Hinged, Pin Drive with Split Insert Bowls and Type CB Split Casing Bushing for casing to 20" Varco Type 27HDP Roller Kelly Bushing Varco DP, DC, and Casing Slips and Safety Clamps Cedco Wireline Unit, 25 HP, 25,000' of .092" line King Circulating tk:ad & Wireline Stripper Okoh Mud Saver Bucket I-R Air Hoists, 1--ODR100A24, 1--ODR40A15 Drill String & Downhole Tools 'Substructure & Equipment Drilling Instrumentation Mud Circulating System Mud Trip Tank, capac~Ly 22'/~ bbls Delmag Model D-30 Diesel Casing Hammer with lead and accessories for 16" through 40" 5" Grade G Drill Pipe, 18,000', plus Pup Joints 5" Hevi-Wate Drill Pipe, 30 Jts Drill Collars, NO-WALL-STICK, Hardbanded, 9V~", 8", 6V~" Baker Model G Full Flow Float Valves Gray X-Hole Float Valve & Release Tool Subs--Bit, Lift, Kelly Saver, Junk Basket, and Crossover Christensen 6%"x3" Marine Series Core Barrel Bowen Fishing Tools for 81/W to 26" hole size Lower Skid Base, 30'x50', with cellar deck having work area and BOP storage stumps, longitudinal travel provided by hydraulic cylinders and claw bases Upper Skid/Substructure, 30'x30', with .hydraulic cylinders and claw bases for transverse skidding 8' each side of center BOP Handling System with two 25-Ton Trolleys, two Hydraulic Hoisting Winches, two I-R Air Hoists for trolley travel, winch/hoist Control Stand Utility Air Hoists, four I-R Model ODR40A15 70 cu. ft Air Receiver for rig service C-E Drawworks Console Ross Hill SCR Driller's Console Auxiliary Driller's Console with running lights/remote controls: DC Motor Blower Lights Drawworks Oiler Low Pressure Light Mud Charging Pump Lights Mud Pump Chain Lube & Liner Wash Lights Shale Shaker Motor Lights Brake Cooling Water Temp/Level Eights Brake Cooling Pump Lights & Controls Hydraulic Power Unit Lights & Controls Desilter/Desander Pump Lights & Controls Totco Instrumentation Console displaying' M-D Type E Weight IndicatOr Rotary RPM & Torque Tong Torque (EZY-TORQ Unit) Swaco Driller Control Pump Pressure (2) Pump Stroke Rate & Counter Pit Level Indicator Mud Flow Indicator Mud Gain/Loss Indicator 'l'otco 6-Pen Drilling Recorder, Model .62-A Totco 2-Pen Drilling Recorder, Model DR2W Totco Mud Flow Sensor/Recorder Unit No. F Totco Vertical Pitometer/Recorder Unit No. L-4 'fotco Deviation Recorder Unit No. 6, Double 0°-8° Two C-E Model FA~1600 7'/2"x12" Triplex Mud Pumps, each chain driven by two EMD D79MB 800 HP DC Motors, with suction desurger, pulsation dampener, (8) Bulk Material System and Cameron reset relief valve One C-E Model F--350 6:~fl"x7" Triplex Shear Mud Pump chain driven by a GM12V71N radiator-cooled diesel engine, witl~ suction desurger, pulsation dampener, and Ca,heron reset relief valve Three Mission 5x6 Centrifugal Chargfng Pumps with 12" impellers, each driven by one 40 HP 1200 RPM AC motor. Dual Mud Standpipe & Manifold, 5~ ~¢" 5000 PSI WP, with Cameron Flex-Seal Valves, and M-D Pressure Gauges Three NRP Powerflex Rotary Hoses, 3~"x60', 10,000 PSI Test Mud Conditioning Centrifuges Model CRVS-11 Duc. ti High & Mixing Speed Shale Shaker Weico Model 5200 Degasser Pioneer Model S3-12 Dosander Pioneer Model T16-4 Desilter Two Mission 6x8 Centrifugal Desilter/Desander Pumps with 13%" impellers, each driven by one 75 HP 1200 RPM AC motor Shaker Mud Tank, 250-bbl, with sand trap and three compartments Two Mission 6x8 Centrifugal Mud Mixing Pumps with 13%" impellers, each driven by one 75 HP 1200 RPM AC motor Demco No. 61213 Mud Hopper and No. 612 Sack Cutting Hopper Philadelphia Mud Mixers, four Model Petro-10 with 25 HP AC motors for mud pits and two Model MT-02 with 5 HP AC .motors for slugging tanks ...:. Six Halliburton Storage 'ranks, 12' D x 15' High, 1130 cu. ft each, with I-Ii-Level Indicators, Valves and Fittings Two Halliburton Surge Tanks, 5' D, 70 cu. tt each, with Valves, Fittings and Dust Boot Cementing Halliburton Twin HT-400 driven by two GM Unit 8V71 Diesel Engines, radiator-cooled, with Halliburton five-valve "H" Manifold Halliburton Sack Cutting Flopper Logging Foundation and service connections for Units Electrical Well Logging Unit Foundation and service connections for Mud Logger Unit Well Control 21%" BOP Stack Equipment Rucker Shatter Spherical Preventer, 2000 PSI WP, 21%" Bore, with clamp hub bottom and studded top Cameron Type U Dbl, 2000 PSI WP, 21%" Bore, with clamp hub top and bottom, shear rams and 5" rams., and '~' "clamp hub outlets four ~/,6 13%" BOP Stack Rucker Shatter Spherical Preventer, 5000 PSI WP, 13%" Bore, with clamp hub bottom and studded top Cameron Type U Sgl, 10,000 PSI WP, 13%" Bore, with clamp hub top and bottom, blind rains, and two 3'..',~" clamp hub outlets Cameron Type tJ Dbl, 10,000 PSI WP, 13%" Bore, with clamp hub top and bottom, 9%" rams and 5" rams, and four 3' ,,," clamp hub outlets Additional set r.,, 7" .~ tarns and rams Kill and Choke Assemb,y, 6 lines with Cameron Type F 3'.,;~" Manual and Hydraulic Valves, Cameron Check Valves and Pressure Gauges Cameron Payne Accumulator Unit, 270-gallon 3000 PSI WP, combination air and electric motor, automatic, with Payne six-station Fluid Control Manifold Two Payne Graphic Remote BOP Control Panels, each six-station, pneumatic operation Cameron Choke Manifold with 3t/,," Type F Valves, three Positive Chokes and provision for one Adjustable Choke Mud-Gas Separator Regan Type KFDS Diverter Assembly with Fixed Support Housing, Telescoping Joint with hub clamp/flange adapter to fit each BOP stack, dual flow lines with pneumatic operated 12" sliding blind valves Diverter Control Panel for operation of all diverter functions and flow line valves Cameron Model DP1092C 10,000 PSI Test Pump, air-driven, for supplyin, g test fluid to BOP stacks, choke/kill lines, and choke manifold HULL EQUIPMENT central Air System Cold Start Air System Water Makers Hydraulic Power Unit Brake Cooling Water System 'Pollution Control 2--Worthington Rollair Model 125/125 Rotary Screw Compressors;, each rated 476 SCFM at 125 PSIG and driven by one 150 HP AC motor, with sequence- alternator control unit, and aftercooler 2--Worthington Model 120A Refrigerated Air Dryers, each' rated 600 CFM at 125 PSIG, packaged and piped with 125/40 PSIG regulator, Centrifix RW5" separator', and safety relief valve --Air Receiver, 53 cu. ft, 150 PSIG WP 1--Worthington Model ED ComPressor, rated 20 CFM at 250 PSIG, driven by a Lister Model SR2 air-cooled diesel engine --Air Receiver, -32 cu. ft, 400 PS[G WP 2--A~lua-Chem Model S300SPEC-E Vapor Compression Distilling Units, each rated 330GPH output, with electric motor "' . driven compressor - ' --Aquafine Model CSL-24 Ultraviolet ' Sterilizer --Lamb Model LP364-2 Dual Tandem Unit, rated 3000 PSI, driven by two 60 HP AC Motors, complete with reservoir, valves and controls. For'supplying hydraulic fluid to power tongs, EZY-TORQ, casing stabbing boom, BOP handling winches, and substructure ' skidding jacks --Specific Offshore Model C2606 Unit with two 2x3 Centrifugal Pumps driven by '40 HP AC motors, two heat exchangers, Iow level switch and temperature' sensor, 30-bbl tank --Demco Model WT-6000-C Waste Treatment Unit --220-bbl Bilge Holding Tank --660-bbl Skimming Tank --35-bbl Dirty Oil Tank Service Purnps Tank/Draft Gauging System Welding System Cranes & Deck Outfit Safety & Lifesaving. Radio & Communications ,-umps and manifolding for w~tste fluid control 3--Raw W[~ter Pumps, each rated ~200 GPM at 126' total head and driven by a 50 HP AC motor, 12" 3-stage vertical turbine unit with 83' column assembly and 8" discharge head 1--Potable Water Pressure Set with two 5 HP AC motor-driven vertical pumps each rated 70 GPM at 70 PSIG, and one 200-gallon prpssure tank with .start/stop pressure switches and gauge 1--Sanitary Water Pressure Set, dual pump unit, each rated 70 GPM at 70 PSIG, same as potable water set 2--Drill Water Pumps 2--Fire Pumps 2--Bilge & Ballast Pumps 2--Fuel Oil Transfer Pumps 1--Dirty Oil Transfer Pump Electrical Level Gauges in all water and fuel hull tanks Electrical Barge Draft Gauges (3) Central Display Panel for tank level and draft Central System with fixed wiring and outlet receptacles for portable welding leads, two DC electric machines each rated '400 A 2--LeTourneau PCM-80AS Revolver Cranes, AC & DC power, 100' boom, rated 25 tons at 30' ra¢lius 3--LeTournea'u W-1500-TS Moorir~9 Winches, AC motor driven, two-speed, with 1 V~" rope, rated 50,000-lb line pull and 130,000-1b brake capacity 3--8000-1b State-Type Anchors with crown pendants and buoys 4--Heavy Duty Smit-Type Quick-Release Towing Pads 1--Tow Bridle Recovery Winch Bollards, Cleats & Chocks to meet regulatory body requirements 3--Hand Winches to handle leg jetting hoses Two Lifeboats and one Rescue Boat in compliance with regulatory bodies Life Rings & Life Jackets in compliance with regulatory bodies Combustible and Toxic Gas Detecting System including: 14 Sieger Gasalarm combustible gas sensors 4 Bullard H,S sensors Central Display/Alarm Panel Fire Detection System Fire Fighting Equipment Remote Emergency Shutdown of blower fans and fuel transfer pumps Marine lights, shapes, signals and aircraft obstruction lights in compliance with regulatory bodies 400 W SSB Transmitters &. Receivers FM/VHF Radiotelephone AM/VI-IF Radiotelephone VHF Emergency Transceivers & Beacons Portable Lifeboat Radios Public Addresser System Intercom Telephone System x. I~ELL BORGSTEN DOLPHIN SELF-ELEVATING DRILLING PLATFORM 300' WATER DEPTH D 118' [:: 2 [1[1 ~(~o) Appendix "B" 12" Divert( Line Telescopic Regan KFDS Diverter ,f" RKB 2" Return Flow Line .Legend 1. Cameron "U" Single 5000# WP 2.. Hydraulic Remote 3. Check valve lO,O00# WP 4. Gate Valve 5. Cameron "U' Double 5000# WP 6. Cameron "U" Double 2000# WP 7. Meter - lO,O00# WP Rucker-Shafer Casing lead - 30" Conductor '20" Casing --- 13-3/8" Casing ..... 9-5/8" Casing I 20" 2000 psil I .I I I BOP Lr-=c~_---- ~_?J L-- .... · Surface Hole Stack Borgste.n ~olph!n BOP Schematic (Not to scale) (11) CHECK LIST t-~)R ~-~ ?~TJ, PERMITS Yes No Remarks 1. Is the permit fee attached ..................... ~ 2. Is well i:-.:) be located in a defined pool .............. q 3 Is a rea~ :-;ter~ s~ey plat attached ................ 4. Is well ~,'x::ated pro~r dis[~ce from proper~y line 5 Is well L::aated proper dist~ce from other wells ........... Is sufficient mdedica[~ acreage available in ~is 7. Is well [o be devia[ed ....................... 8. ~Ls o~rator ~e only affec[ed ~r[y ................ 9. C~ ~t be approved ~fore ten-day wait ............. 10. ~es o~rator have a ~nd in force ................. tl. Is a consolation order needed ................ 12. Is a~nis-~-ative approval n~d~ ................. 13. Is conductor string provided .................... 14. Is enough cement used to circulate on conductor and surface .... 15. Will comers',.-, tie in surface and intermediate or production strings 16 [fill ceneni_ cover all known productive horizons .......... ~_ 17. Will surface casing protect fresh water zones ........... ~_ 18. {'frill all.~ qsing give adequate safety i_n collapse, tension & b%u:st . /.~.~ 19. Does BOPE have sufficient pressure rating - Test te ~OoO ps~g . ~u~__ [4) Casg. - (5) BoPE . - (6) Pi~ .......... Revised 4/14/78 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 APPENDIXi ., No Special'effort has been made to chronologically organize this category of information. .o ~t1¥ 6.~ 33f, 3.2 I)3 ,:t / 14 3.3 14 4tip 3.2 12 ,i't I :.4 3. I I 4 472A f:~./ ~5 3.0 4't'~d 7.h 311 3.0 t~ 't ,3 4 3. O 1 ~13t. d 3 .~ 2{>{~ 3.0 4140 20.5 264 3.0 q '! 4 Z 3.0 474 *, 3.0 t 9 4 t b o 3. o 22 4752 3.0 ,4 7 b 4 3. 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