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Home My WebLink About183-046 ge Project Well History File~ver Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. j_ ~:~-.~- 0 ~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: .- [], Logs of. various kinds NOTES: [] Other BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE; /S/ Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ Scanning Preparation x30= + BY: BEVERLY BREN VINCENT SHERYL~OWELL = TOTAL PAGES _~_. ~"' Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: BY: Stage 2 BY~ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES) PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~K~ YES NO IF NO IN STAGE 1 , PAGE(S) DISCREPANCIES WERE FOUND: YES NO BEVERLY BREN VINCEN~ARIA LOWELL DATE: ¢ ~ III IIIIIIIIIII Jllll RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL General Notes or Comments about this file: DATE: /S/ Quality Checked Memorandum To: State of Alaska Cancelled or Expired Permit Action EXAMPLE: Point Mclntyre P2-36AXX API# 029-22801-95 Oil and Gas Conservation Commission This memo wffi remain at the front of the subject well file. Our adopted conventions for assigning APl numbers, permit numbers and well names did not specifically address expired or cancelled permits. This omission has caused some inconsistencies in the treatment of these kinds of applications for permit to drill. Operators have asked us to adopt formal procedures for this class of permit application in order to prevent future database disparities. If a permit expires or is cancelled by an operator, the permit number of the subject permit will remain unchanged. The APl number and in some instances the well name reflect the number of preexisting reddlls and or muitilaterais in a well. In order to prevent confusing a cancelled or expired permit with an active well or multilateral these case sensitive well identifiers will be changed for expired and cancelled applications for permits to ddll. The APl number for this cancelled or expired permit is modified so the eleven and twelfth digits is 95. The well name for a cancelled or expired permit is modified with an appended xx. These procedures are an addendum to the APl numbering methods described in AOGCC staff memorandum "Multi-lateral (wellbore segment) Ddlling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. e McMains - ~ Statistical Technician December 20, 1984 D. H. Jones Exploration Coordinator - Alaska Exxon Corporation Pouch 6601 Anchorage, Alaska 99502-0601 Re., Alaska State J-1 Alaska. State R-1 Dear Mr. Jones .. The. API numbers for the subject wells were erroneously assigned and are therefore cancelled. The correct API numbers for these wells are z Alaska State J-1 Alaska State K-1 .50-179-20007 .50-179-20008 The incorrect numbers, 50-223-20016 and 50-223-20017, will not be reused. Sincerely yours, /John A. Levorsen Senior Petroleum Geologist B.lg.3 PATE:_.. 0_~', I $-- ~3 _ . 'PROFb-C:,EP · ~ii--111-~1 I1--- 1 ~/ SbT A'r_lzoooi %!2' AT ' I/,,oo,.., ' March 15, 1983 Mr. D. H. Jones. Exploration Coordinator-Alaska Exxon Corporation Pouch 6601 ~chorage, Alaska 99502 Re: Alaska State K Exxon No. ! Exxon Corporation Permit ~o. 83-46 Sur. Loc. 2300'FSL, 1000'FEL, Sec. 1, T6N, R22E, U?~. Bt~ole Loc. S A ~ E. Dear Mr. Jones: Enclosed is the approved application for permit to drill the above referenced well. If coring is mm! . ' a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud ~.o~ ~ are required._ An inclination.survey is required as 'per 20 AAC 25.050(b)(5). If available, a tape containinK the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys o Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska ada~nzstrative Code). Prior to commencin? operations you may be contacted by the Habitat CoordinatOrYs 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 18, Alas~ Administrative Code, Chapter 70) and by the Federal ~ter Pollution Control Act, as amended. Prior to co~cvmncing operations you may be contacted by a representative of the Department of Enviro~enta! Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout Mr. D. H. Jones Alaska State K Exxon No. 1 -2= March 15, 1983 prevention equipment so that a representative of the Commission may be present 'to witness testing of the equipment before the surface casing shoe is drilled. Where a dtverter system is required, please'also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Ve~_truly yo~urs, d~, h''~ :~? / ..~ . _/.-~--... / .f : :: .~ ....,'~ Chairman of Alaska Oil and Gas Conse~Vation Commission Eno lo sure cc,. Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. E) ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99,50:2 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION D.H. JONES EXPLORATION COORDINATOR -- ALASKA March 3, 1983 Exxon Alaska State "K" Well No. 1 ADL 344030 Mr. C. V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Chatterton: Exxon Corporation submits the following in regard to the above captioned well: 1) State of Alaska, Oil and Gas Conservation Commission Permit to Drill, Form 10-401, in triplicate. 2) $100.00 check in payment of the required permit fee. It is ExXon's intent to drill this well in the~. We are submitting the application at this time to ~atisf~ permitting requirements of the North Slope Borough. Yours very truly, D. H. Jones 211B/55 A DIVISION OF EXXON CORPORATION RF£E[VED ^bsk~ Oil & '--~,.~ ...... ,-. ...... An ~.hnr.n~ STATE OF ALASKA ¢-..., ALASKA O,~ AND GAS CONSERVATION COt..,,vllSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN 2. Name of operator Exxon Corporation 3. Address Pouch 6601, Anchorage, AK 99502 lb. Type of well EXPLORATORY ~] DEVELOPMENT OIL [] DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE [] 4. Location of well at surface 2300' FSL and 1000' FEL Section 1, T6N-R22E, U.M. At top of proposed producing interval At total depth Straight Hole 5. Elevation in feet (indicate KB, DF etc.) Approx. 360' KB 6. Lease designation and serial no. ADL 344030 12. Bond information (see 20 AAC 25.025) American ]]ns. Co. Type 0il & Gas Consv. Surety and/or number 5208885 9. Unit or lease name Alaska State K 10. Well number Exxon No. 1 11. Field and pool Wildcat 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 50 Mi, ESE of Deadhorsemnes' 1000' feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 16000' Straight Hole feet 5760 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT feet. MAXIMUM HOLE ANGLE oI (see 20 AAC 25.035 (c) (2) Amount $200,000.00 15. Distance to nearest drilling completed 13 ~w~r N of Mobil o~ Belif~ef 18. Approximate spud date 10/1/83 7~0¢} psig@ Surface 9980 psig@,~;d~0~ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight See At CASING AND LINER Grade / Couplingl Length MD TOP TV D M D BOTTOM TV D I I I I I I (include stage data) 22. Describeproposedprogram: Blowout preventers: A 20"=annular BOP with diverter lines will be installed on the refrigerated conductor, as shown on the attached sketch. The diverter will be removed prior to opening the pilot hole to 26" to 800'. The same diverter will be used on the 20" conductor to drill to 3300'. A 13-5/8" 5000 psi WP annular BOP and three 13-5/8" 10,000 psi WP ram BOP's will be installed on the 13-3/8" casing as shown on the attached sketch, and will be used along with the 10,000 psi WP choke manifold for the remaining drilling and testing operations. Anticipated surface pressures are shown in the attached casing design section. Arrangement of the choke manifo~ld J8 also shown in an attached sketch. !~[~ V ~ [,} -23. I hereby certify,/~,t~,~.ng is true and correct to the best of my knowledge . ' '~~/_~¢/~i~ Explorat ionA~8!~r~k'h~~r~:;.; ;:,: SIGNED ~__ TITLE Alaska D~TE 3~3-83 The space below for Commission use CONDITIONS OF APPROVAL Samples required ~,Y ES []NO Permit number APPROVEDBY Form 10401 Mud log required ~YES [] NO Approval date Directional Survey required []YES ~10 APl number 5o- ¢-'~ :~ ' SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE by order of the Commission March 15, 1983 Submit in triplicate Alaska State K Ex?--,. No. ! ! DiVERTER OPEP~ATING PROCEDURE The "reserve pit" manual valve should al~,~ays be open. The flare pit diverter valve should remain closed unless the wind direction makes diverting in this direction hazardous, i, Then the flare pit valve is open, close the reserve pit valve. Before spudding, blow air through the diverter syst~'m to ensure that there is no blockage. Water or mud is not to be pumoed through the system, since it will be difficult to ensure complete drainage of the lines. Run operational and crew tests on each tour. Open the hydraulically operated valve and close the annular preventer. Drain the riser and annular preventer below the diverter side outlet before testing to prevent liquids from entering the diverter lines. if the well flows, immediately close the annular preventer, which will simultaneously open the diverter valve. Pump mud at the maximum possible rate. Start the snow melter. T~ -- ~ ~ al i the available mud is pumped and diverted pump ~ater at i BPM to keep the drillpipe open. Manifold the suction from the snow melter so that water can be pumped at 1 BPM and at temperatures above 60°F. If feed water temperature falls below 50°F, displace the drillpipe ~.~ith diesel and stop pumping. This will avoid freezing and hydrates. Don't do this without concurrence of the Drilling Operations Superintendent. ~,Thile pumping water, mix 13 ppg mud. !'.~en ready, pump the mud down the well at the maximum possible rate. Under no circumstances is the well to be shut-in at the surface. PRESSURES EXCEEDING P~TING OF ANNULAR BOP - !~ile circulating out a kick during the drilling of the deeper portion of this well, surface pressures could exceed the 5000 psi rating of the annular preventer. This should not happen when the annular preventer is used to shut-in the well initially. The following procedures will be used: If a kick is indicated, stop the rotary, pick up the kelly and shut-in the well with the annul, ar~ preventer. Alaska State K Ex-~'~ No. ! 2 If the decision is made to circulate out the influx with the annular preventer, carefully monitor the casing pressure. If at anytime the casing pressure approaches the rating of the annular preventer, shut down and transfer control to a ram preventer. CASING DESIGN CRITERIA: Surface- 13-3/8" @ 3300' o Burst - Considers gas gradient to the surface causing lost returns at the shoe assuming maximum exoected leakoff gradient. External fluid weight 9.0 ppg. Casing Design Surface Pressure (CDSP) CDSP = (Max. shoe leakoff gradient - gas gradient) x casing depth = (15.0 x .052 - 0.i0) 3300' = 2244 psi Permafrost F_~ezeback'v~ - Considers maximum external collapse gradient of 1.44 psi/ft and minimum internal fluid weight of 9.0 ppg. Maximum Collapse Pressure (MCP) MCP = (Max. external gradient- min. fluid gradient) max. permafrost depth (1.44 - 9.0 x .052) 2000 1944 psi Permafrost Thaw Subsidence - 13-3/8" 72#/ft L-80 Butt post yield strain performance exceeds the requirements for Prudhoe Bay Field rules, based on worst case well spacing. o Minimum Exxon Safety Factors Burst I .312 Collapse 1.00 Tens ion i. 50 PROTECTIVE 9-5/8" @ 12,000' o Burst - Considers gas kick of sufficient intensity and volume to cause lost returns assuming maximum expected leakoff gradient and casing filled with water. External fluid weight 9.0 PPg' !'-~ ~" ~i-i ~" ~ '" ~ ~' ~ Alaska State K Ex?-n No. 1 3 ~' Casing Design Surface Pressure (CDSP) CDSP = (Max. shoe leakoff gradient - water gradient) x casing depth (16.0 - 8.33) .052 x 12,000' 4790 psi Collapse - Considers surface pressure = 0 psi, internal fluid weight 8.33 ppg and external fluid weight 12.0 PPg Maximum Collapse Pressure (MCP) MCP = (External fluid gradient - internal fluid gradient) casing depth - surface pressure (12-8.33) .052 x 12,000 - 0 2290 psi Minimum Exxon Safety Factors Burst 1.312 Collapse 1.00 Tension 1.50 PRODUCTION 7" @ 16,000' Burst - Considers shut-in gas well surface pressure and formation pressure of 12.0 ppg. Casing Design Surface Pressure (CDSP) CDSP = (Max. anticipated formation gradient - gas gradient) casing depth (12.0 x .052 - 0.137) 16,000 7800 psi Collapse - Considers pressure = 0 psi, internal fluid weight = 0 ppg, and formation pressure = 12.0 ppg Maximum Collapse Pressure (MCP) MCP = (Formation gradient - internal fluid gradient) casing depth - surface pressure (12.0 x .052 - 0) 16,000 - 0 9,980 psi RAM: rms 211C/3 3/3/83 Exxon ~.{inimum Safety Factors Burst 1.312 Collapse 1.125 Tension 1.50 EXXON COMPANY, U.S.A. Plan of Operations Alaska State "K", Well No. 1 GENERAL This well will be a straight hole drilled from a surface location at 1000' FEL, 2300' 'FSL, Section 1, T6N-R22E, U.M. Contingent upon regulatory approval, ice road construction will begin approximately March 20, 1983 and the well spudded on or about November 1, 1983. Drilling and testing will require approximately five months. NATURAL ENVIRO5RfENT The proposed drillsite is located in the Prudhoe Bay Uplands about 20 miles .south of the Alaskan coastline. It has an average elevation of 325 feet above sea level. The depth of the perma- frost in this area is expected to be about 1600 feet and the active surface layer or thaw zone is from one to three feet. Since the ground cover acts as insulation limiting the depth of the active layer, removal or damage to the ground cover, particu- larly in areas of any appreciable slope, is a major factor in causing erosion. Consequently, every possible effort will be made to protect the surface from unnecessary damage. There are no established roads, airstrips, housing, or other facilities in the area and, because of the nature of the terrain, heavy vehicular traffic can operate only during the winter while the ground and surrounding sea ice are froZen. Prudhoe-Deadhorse is the nearest staging area and airstrip with permanent facil- ities for handling cargo and housing personnel. Arctic climatic conditions contribute to the harsh environment. These conditions include relatively cold temperatures year-round, strong winds, little annual precipitation, and occasional reduced visibility. Temperatures vary from a high in the 40 to 60°F range, in the summer to a low of -50 to -60°F in the winter which, with the chill factor, may reach -100°F or lower. Surface winds are 'predominantly from the east at an average velocity of 12 miles. per hour along the coast with a velocity range of 35 to 50 mph associated with winter storms. Total annual preCipitation is in the range of 4 to 6 inches which includes 12 to 48 inches of snowfall. Various species of wildlife exist in the area. Wolves, wolverines, foxes, polar bears, bare land grizzlies, and caribou · Alaska State "K", Well No. 1 -2- March 8, 1983 may be. present. Bird life is limited primarily to the families of falcons, ptarmigans, owls, and crows, with waterfowl and most other birds having migrated from the area for the winter. LOGISTICS Gravel for the pad construction will be hauled from Exxon's stockpile on the Pt. Thomson #3 pad or from the Pt. Thomson gravel source immediately adjacent to the Alaska State C-1 pad. A tundra ice road to the source will be constructed for the truck hauls. During drillsite construction and mobilization, access to the propOsed location will be via ice roads. The major sea ice road will follow the Beaufort Sea shoreline, extending from the Prudhoe Bay East Dock to Exxon's Pt. Thomson #3 drilisite. A tundra ice road will continue from Pt. Thomson #3 to the Alaska State C-1 gravel source and continue in a south-westerly'direc- tion approximately 20 miles to the proposed location. The road will serve to transport construction equipment and supplies from Deadhorse as well as to support the gravel haul operations. Mobilization of the rig to the drillsite by rolligon will take place in October, or as soon as rolligons are permitted to travel across the tundra. The most probable scenario would be to barge a rig during the summer to the Point Thomson #3 pad, and store it at this location until mobilization by rolligons. The barging would take place during late August or September 1983. After rig.and equipment mobilization is complete, helicopters, rolligons and other all-terrain vehicles will be used for sup- port. An ice road to the location may also be constructed for rig support. An ice landing strip, approximately 5000 feet long by 150 feet wide will be constructed on the tundra adjacent to the pad to facilitate air transportation. Hercules type aircraft, along with Twin Otters will be used for rig support after the ice landing strip is constructed. . DRILLSITE CONSTRUCTION Contingent upon regulatory approval, the gravel pad construction 'will begin about March 20, 1983. The drillsite will measure approximately 700 feet by 400 feet and will have a surface elevation of approximately +327 feet. The pad will consist of 2" of expanded polystyrene insulation, placed on the graded tundra surface, overlain by a liner, and 24" of gravel (minimum compacted thickness) o Approximately 18,000 cubic yards of gravel will be-required for the pad construction. The ~gravel will be transported by truck or rolligon via~ ice .rO~fl,.,from .! ,~., ~ . . .' · .~ . . .'Alaska State "K", Well No. 1 -3- Mar ch 8, 1983 the stockpile at the Point Thomson #3 pad, or the gravel pit adjacent to the Alaska State C-1 pad. Alternatively, the insulation material will be deleted and the pad constructed of'5 feet of~gravel (approximately 45,000 cubic yards). Gravel hauling, loading and placement equipment will be used to build the pad at the new drill.site location. Blasting may be used to excavate the reserve, fuel, and burn pits. A description of the three pits is in the Drilling Operations Section, immedi- ately following this section. The attached plat contains a drillsite layout showing the location of these pits. Berms will be constructed around all pits. The proposed sequence for drillsite construction will be as follows: · Construct ice roads and ice landing strip from March 20 to April 20, 1983. The AADCo 5 Camp at North Star Island may be used by con- struction personnel prior to demobilization of the rig. A temporary portable camp will be used at the gravel source or at the proposed drillsite for ice road and drillsite construction crews until construction is complete. · Transport gravel loading and hauling equipment via ice road from Deadhorse to the gravel source and proposed location in early April, 1983. · Transport gravel via tundra ice road to the drillsite for gravel pad construction, during April 1983. 4. Construct reserve, fuel, and burn pits in April. · Barge the drilling rig, camp, and miscellaneous supplies to the Point Thomson 3 oad in late August ~r September, 1983. · Mobilize the .rig and supplies to the drillsite by rolligon during October, 1983, or as soon as rolligon access on the tundra is permitted. · Construct the ice landing strip adjacent to the pad. Rolligons, all terrain vehicles, Twin Otters, and/or hercs will be used for rig support. Alternatively, a coast ice road from the East Dock to Point Thomson 3 and tundra ice road tO the drillsite may be constructed. Alaska State "K", Well No. 1 -4- March 8, 1983 The dates shown in the proposed construction sequence may vary with weather and ice conditions. DRILLING OPERATIONS The K-1 well will spud approximately November 1, 1983. Drilling and testing will require approximately five months. After testing, the rig will be stored onsite until it can be demo- bilized back to Deadhorse via Hercules aircraft or ice roads, (approximately April 1984). The drillsite layout is shown on the attached plat. An impermeable plastic sheet will be installed under the drilling rig to collect liquid drainage and direct it to the well cellar for recovery and disposal. The wellbore will be designed for annular injection for the subsurface disposal of waste liquids. Prior to setting the casing strings, the mud wiI1 be disposed of in the reserve pit. After the casings are set, drilling fluids will be injected down the 13-3/8" x 20" or 9-5/8" x 13-3/8" casing annulus as neces- sary. Cuttings will be retained in the reserve pit. The welded steel fUel tanks will be placed in the fuel pit designed to contain 110% of the total capacity of the fuel tanks. The fuel pit will be lined with an impermeable material. A burn pit will be located a safe distance from the rig to permit routine burning of well test gases, combustible waste materials and the ~emergency burning of well test liquids. Equipment and supplies will be stored on th'e drillsite pad. the tundra~ is frozen, dry mud material, tubulars and other supplies may be temporarily stored adjacent to the pad. Wtlei1 Water for drilling operations will be taken from state approved small lakes near the rig, or from the water sOurce just south of the Exxon Alaska State C-1 drillpad,, or from a large eight-foot deep lake in Section 22 and 23, TgN, R23E, UP~. Another alter- nate water source would be to drill a shallow water well in the vicinity of the Canning River. A snowmetter will be used to supplement water requirements until shallow lakes closer to the rig thaw ih the summer. The water will be processed through the rig water treatment unit before use in the camp. WASTE HANDLING PROCEDURES The following ~aste handling procedures will be observed during drilling operations: · Sewage Effluent and Gray Water - Sanitary sewage will be treated with a state-approved sewage disposal unit. .o .- Alaska State "K", Well No. 1 -5- March 8, 1983 Treated effluent from this unit ~vill be combined with gray water from the camp kitchen and bathrooms. The treated effluent and gray water will be discharged onto the tundra. The water may also be used for mud and rig wash water. Two 25,000 gallon sewage effluent tanks will be provided for the standby storage of these liquids during upset conditions. · Cuttings ~nd Drilling Fluids - A reserve pit with an estimated capacity of 50,000 barrels will be con- structed. This pit will be used to permanently dispose of drill cuttings and fluids. Drilling fluids will be injected down the casing annulus as necessary. · Domestic Garbage will be disposed o'f in a state- approved incinerator. Incinerator ash will be disposed of in the burn pit. · Combustible Wastes such as paper, wood,' and cardboard will be incinerated or open-burned in the burn pit. · Noncombustible Wastes such as scrap metal, batteries, drums, wirelines, etc., will be hauled to a state- approved site for disposal. · Well Test Fluids - Produced gas will be flared. Produced liquids will be injected down the casing annulus or hauled to a state-approved site for dis- posal. · Waste Oil will be injected in the casing annulus or hauled to a state-approved site for disposal. SURFACE PROTECTION AND RESTORATION PLAN During drillsite construction and equipment mobilization, surface transportation to the drillsite will be primarily over ice roads. Shortly after mobilization is complete, rolligons and other applicable forms of transportation may be used as an alternate to maintaining the ice road. Alternatively, helicopters and rotligons may be used to supply the drillsite with fuel and supplies. 'Special procedures for drilling are required by the unique characteristics of the permafrost area. Casing cement used through the permafrost zones is a special composition to reduce possibility of freezing and.other casing problems. Casing is run and cemented through the permafrost, and in the event of produc- tion or interruption of operations, the uncemented casing must be protected by the use of non-freezing fluid. · Alaska State i'K", Well No. 1 -6- Mar ch 8, 1983 At the completion of the well, the location and adjoining area will be cleared of all waste materials. All pits will be back- filled and leveled. VELOCITY SURVEY A velocity survey will be made prior to the completion of the well. In this procedure, surface holes will be drilled near the wellbore, and an airgun will he used as the energy source for the survey. A Vibroseis unit may be used as substitute for an airgun. An alternate survey method which may be used would utilize a 40-inch diameter casing hole, 40 foot deep, located on the drill pad near the wellbore. The hole would be filled with brine just prior to the survey and an airgun would be used as the energy source. Another alternate survey method will be the use of a water filled tank, 10 feet in diameter and 20 feet high installed on the pad. An airgun would also be used with this survey method as the energy source. DEVELOPMENT PLANS If oil is discovered in sufficient quantities to warrant future development, the Prudhoe Bay to Vatdez oil pipeline would be the probable marketing outlet from the area. Oil and casinghead gas would be processed through central oil gathering facilities with~ oil transported to the Trans-Alaska Pipeline System. If commercial quantities of gas are discovered, development of a gas market outlet would depend on the results of studies to examine the marketing of gas from the Prudhoe area. NB: rms i ~ NPB/25 .... '~J .... ~ ~ ..... ~ T. 7N. T. 6N. 26 i ? 24 20 ~4 36 ,i ~'~ 1000~' S L"/ ~ AS- STAKED 5 ' ' ;S ~ALASKA STATE K- I i ] i~I--LA-r. = 69°54'09.9,'' '~L ~LONG.= t46° 30 55.30 TOPO FEATURES TAKEN FROM MT M!CHELSON (D-5), ALASKA SCALE: I"= ! MILE r..-:,-~r~j 0 le:'~-.-., - :M_~ ',.;, ~ ,:.:...,. ~., ~. ,.~:~ ,~:'~. F.,~ ~, CERTIFICATE OF SURVEYOR I hereby certify that t om properly registered and licensed to pratt:ce iand surveying ~n fhe S~mte o~ ~iOSKQ and fhot tnJs plat represents a iocotlon survey mode by me or under my direci supervision and that ail details are correct. =_ ..... PEV;SED WELL NAME 3- 5 -83 AS STAKED WELL LOCATION ALASKA STATE K-I LOCATED IN SE I/4 PROTRACTED SEC. I~ TGN,R ~.2E.,UMIAT MERIDIAN, AK. F '.j~ EXXON COMPANY U.S.A. BESSE, EPPS & POTTS ;.'.~h)R,'-.GE . ., ' ~r-~ . ~4 '~ ;~:;- TYPICAL 2000 PSI W.P. DIVERTER STACK AND LINE for use on ALASKA STATE"K"' EXXON NO. ~1 Trip Tank Flowline ~ 2000 psi W.P. Annular BOP OTo burn pit TQ reserve pit 20" spool 28" x 36" Refrigera.ted Conductor 20" or Cas ing Minimum 6" diverter lines 1. Full opening hydraulically operated valves interlocked such that the diverter line valve will always be open before annular BOP is closed. 2. Full opening manually operated valves with one valv~talways ihthe open position to control flow to reserve oit, . or burn pit~l,~]{~,i~!~.~';''''g, -~' ~y. ~/7~ TRIP (~ 6'~ ~ -- OOP ~ 5000 psi W.P. [RA" BOP] Pipe lO.DOD psi W.P. ~ MANIFOLD RAM BOP Co .m~_-.~n.-nt Snec! fi cmti OhS 1. Screwed Plug or Gate Valve - 2" .~ize provided with A-section 2. Screwed Plug Valve - 2" size 3. -Screwed Tapped Bullplug with Needle Valve and Pressure Gage 4. Flanoed Plug or Gate Valve - 2" size provided with wellhead 5. Flan~ed Pluo Valve - 2" size with co, anion flange to protect valve flange face 6. Flanged Plu~] or Gate Valve - 2" minimum size ?. F1 anged Hydraul ical ly Controll ed Gate Valve - 3" B. Flanged Flapper Type Check Valve - 3" g. Flanged Hydraulically Controlled Gate Valve - 4" minimum size lO. Flan~ed Plu~ Valve - 4" minimum size. · · II. Top ~f A:~nuiar Preventer must be equipped with an AP1 Flange Ring Gaskel~. All flan;e studs must be in place. ~ 12. The I.D. of the Bell Nipple must no{ be less than the minimum I.D. of the BOP stack. NOTE: All valves on kill and choke-lines lO,OOO psi W.P. Typical arrangement for 13-5/8" 10,000 psi WP BOP Stack for use on 13-3/8", 9-5/8", and 7" casing Alaska State "K" Exxon No. 1 TYr"'"~AL ARRANGEMENT FOR 10,000 PSIG' " L~OKE MANIFOLD FOR ALASKA STATE "K" EXXON NO. · D, M. 7-1&-gl 2.=, 26 24, T. 7N. 1~6N. 4 As- '~ALASKA STATE K- i LONG.:I~6°30 55.30 ~Y:5,814, 170 i2 ? TOPO FEATURES TAKEN FROM MT ~,,4!CHELSON ~,D-5), A. LASKA / ,, [, .. ,. ? ,.i~/'. ,, .' . ,.- , / , i' , -:~/¢2" ', :,. . SCAi E' i": ; MIL L CERTIFICATE OF ! hereby certify that !am prop~-r,y registered 'snd iicensed to practice lend surveying ~r, the S1Jfe ~.~ Aios~,d end fho~ ii]is plot represents o location survey mode by me Or und,~r my direc1 supervisi~..,n and ih~]i / RE'/:SED '¢,'LLL NAME ALASKA STATE K-i L ~:,"/, FL[. ?E i.,'4 !~[~ )TF,~:'.CT~i Ff'? , ! ('N ,'~ ;'~E.,UMIA~, MLI.:',I&L', Ev XQN I } r'- c*c' i- NOTES' I. Fuel Pit Inside Dimensions 210'x 66'x 5' Reserve Pit Inside Dimensions 155'x152' x I0' 3. Burn Pi! Road is 5' Thick. 4. Total Gravel Fill For Pad Construction is Approx. 45,000 Cubic'-Yards. 5. All Pit Slopes are I-i/2: I . 6. Board Insulation May be used to Reduce Gravel Fill Volumes. 7. Contours are based on a Assumed Datum. Actuat Elevation at the Well Site is Approximately 525' MSL SLOPE TO NATURAL zoo' ~oo' '-: ";--"-. '-'~ Ii l-:..x-' ;.-;.'-."- -' -'- .~. I _×,,.,.,..,.,,.,,,.,,, ~/5' GRAVEL FILL g FUEL PIT - 66' / PLAN VIEW Scale I"= 200' i 200' SECTION A- A -- (NTS) PURPOSE: Provide e Ped end Appurtenences For PrOposed Drilling Site. o MILES Proposed Alaska State K-1 LAT. = 69°54'09.91" LONG.=i46oso'55.50" UTM ZONE 6 X= I ,7'0 I ,:394' Y=25~442,6ZI ' ASP ZONE 3 X = ' 455, I Y= 5,8 I 4,170' b:;J!;: 'ii2 1'-',:. 11/2. , . RESERVE PIT 155' ~/ GROUND Proposed Alaska State K-1Drillsite In: SEI/4 SEC. I ,T. 6N.,R.22. E.,U.M.,AK. Neet: CANNING RIVER, NORTH SLOPE ~,pp~icatio, by EXXON CO. U.S.A. SHEET I OF ! DATE 2/3/85 Proposed Casing, Liner and Cementing Program Alaska State K Exxon No. 1 Hole 40" 26" 17-1/2" 12-1/4" 8-1/2" RAM: rms 2ilC/U 9/22/82 Size Csg. 28"x36" 20'l 13-3/8" 9-5/8" 7" Wt. Casing & Liner Setting Depth- RKB Grade Cplg. Length Top Bottom Refrig. Conductor ±60' Surf. 110' 133 106.5 72 47.0 29 32 35 K55 BTC 455' Surf. 500' K55 BTC 300' 500' 800' L80 BTC 3,255' Surf. 3,300' N80 BTC 11,955' Surf. 12,000' Pll0 LTC 9,955' Surf. 10,000' Pll0 LTC 4,500' 10,000' 14,500' Pll0 LTC 1,500' 14,500' 16,000' Quantity of Cement Permafrost cement or Poleset to surf. Permafrost cement to surf. Cement to surface. Approx. TOC 9000' 500' above potential HC zone. CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (9"" thru 11 ) (4) Casg~.~~. J-//-Yv~ (12 thru 20) (21 thru 24) le me 5. 6. 7. '8, 1 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. YES NO Is the permit fee attached ........................................... .. Is well to be located in a defined pool ............ Is well located proper distance from property line oiiiiiiiiiiiiiiii·· ~._~r,~?_ .... -- Is well located proper distance from other wells ... . Is sufficient undedicated acreage available in this Is well t° be deviated and is well b°re pl:t included iii'i iiiiii!'i~~ IS operator the only affected party . . eee ee · · · ....... ,' Can'permit be approved before ten-day'~; ::: :::: ' · lee · ,-'. Does operator bare a bond in force .......................... ......... Is a conservation order needed ...... ~ ............................... ' Is ad ini iv app al need d ' m strat e rov e ..... .... . ........ ......... ...... .. Is conductor string provided - Is enough cement used to circulate on conductor and surface ......... ~ __ Will cement tie in surface and intermediate or production strings ... Wil Wil Wil Is Is Is 1 cement cover all known productive horizons ...................... ~ 1 surface casing protect fresh water zones ....................... ~f~ 1 all casing give adequate safety in'collapse, tension and burst.. ~.~ this well to be kicked off from an existing wellbore ............. old wellbore abandonment procedure included on 10-'403 ............ adequate well bore separation proposed ........................... ~ REMARKS Is a diverter system required . ...................................... ~ Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating -Test to /~,~ psig .. ~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. ~ Additional requirements ............................................. ~ ': Geology: Engineering dVA JKT~J~HJH rev: 12/06/82 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE -----" LZ t