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Home My WebLink About182-019XHVZE Image~oject Well History File Cover 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, /- ~(~--~ .L ~' Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: BY: BEVERLY ROBIN [] Diskettes, No. [] Other, No/Type VINCEN~ MARIA WINDY [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Lo.g.~f various kinds ~'~Other~ DATE:',/~ ./,~).~ Project Proofing Scanning Preparation = = TOTAL PAGES BY: BEVERL~INCENT SHERYL MARIA WINDY Production Scanning Stage 1 PAGE COUNT FROM SCANNED F~LE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~. YES BY: O ROBIN VINCENT SHERYL MARIA WINDY DATE: I&{0'0~ 'S/~ Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES BY: BEVERLY ROBIN VINCE~ MARIA WINDY (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON A~ INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) NO NO RESCANNEDBY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: General Notes or Comments about this file: Quality Checked 12110/02Rev3N OTScanned.wpd Memorandum To: State of Alaska Oil and Gas Conservation Commission Cancelled or Expired Permit Action EXAMPLE: Point McIntyre P2-36AXX AP1 # 029-22801-95 This memo will remain at the from 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 muitilaterals 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 drill. The AP! 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 (weilbore segment) Ddlling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. St-eve McMa~ns - ~ "' - Statistical Technician Oct~r 12, 1982 Mr. D. ~.. Jones ~xon C~pany, U.S.A. Much 660! An~orage, Alas~ 99502 Re= Alas~. State D-2, Pe~t No. 82-19 Bar Mr° Jones Your letter .to me of Oct~r 6, 1982 stated that you no longer planned to dr!lI Alaska State D-2,~- Permit No. 82-19, therefore, ~ a~ returning one ¢~y of your application. We will cancel our file copy and close the subject file. Si n~cerely, ~nnte C& Smith Com~ ssion Enc lo ~re E ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION Re' October 6, 1982 Mr. Lonnie Smith Alaska 0il & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Alaska State D-2 Permit No. 82-19 Sur. Loc.: 305' WEL, 1169' NSL, Sec. 23, T10N, R23E, UM BH Loc.: 5794' EWL, 1414' SNL, Tract BF 114 Dear Mr. Smith' Exxon Company, U.S.A. no longer has plans to drill the above captioned well and therefore we respectfully request the Commission to cancel Permit No. 82-19. If you have any questions, please call the undersigned at 263-3714. Very truly yours, D. H. Jones DHJ'et cc: North Slope Borough, Attn: Shehla Anjum Division of Minerals & Energy Management, Attn: Bill Van Dyke A DIVISION OF EXXON CORPORATION OCT fi 1982 0~! ,?. ~:::~; ~',".'~?,', ........ February 11, 1981 tkir. A. L. He rraa~ Division Drilling I/n{lineer Exxon Corporat ion Pouch 6601 Anchorage, Alaska 99502 Alaska State D Exxon No. i llxX°n Corporat ion Permit No. $2-19 Sur. Loc, 305~L, 1'I69~NSL, Sec 23, TI0~, R23E, Bott~ole Loc: 5794~, 1414~S~L, Tract BF 114. Dear Mr. Hermannl Enclosed is the approved application for perulit to drill the above referenced well. Well samples and a nnld log are required. A continuous direc- tional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the diEitized log information shall be submitted on all logs for copyintf except experimental logs, velocity surveys and dipmeter surveys. l~lany rivers in Alaska and their drainage system's have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.0§.8?0-and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, 'Department of Fish and Garde. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article ? and the reKulations promulgated thereunder (Titl'e 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencin/f operations you may be contacted by a representative of the Department of Bnvironmental Conservation. Mr o A. L. 'Her mann Alaska State D Exxon -2- February 11, 1982 To aid us in scheduling field work, we would appreciate your notifying this office within 4§ hours after the well is spudded. We would al so like to be notified so that a representative of the Co~tsston may be present to witness test tn/: of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please {~tve this office adequate advance notification so that we may have a witness present. Very truly yours C. V. Chatterton Chatl~an of BY ORDE~ O~ TH~ CO~MtS$~ON Alaska 0ti and Oas Conservation Commission Bne 1 o sure Department of Fish & Game, Habitat Section w/o encl. Depart~nt of Bnvironn~ntal Conservation w/o enel. % E ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT OFFSHORE/ALASKA DIVISION February 1, 1982 Re: Alaska State "D" Exxon No. 2 Section 23, T10N, R23E, UM. ADL-312866 Arctic Slope Alaska C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr Chatterton, Exxon Corporation submits the following for the captioned well: State of Alaska, Oil and Gas Conservation Commission Permit to Drill, Form 10-401, in triplicate with triplicate copies of the location plat and contingency plan. Exxon check No. 4623 dated January 28, 1982, in the amount of $100.00 in payment of the required permit fees. For the captioned well, we are also filing the following with the State Division of Minerals and Energy Management: A plan of operation describing the drilling pad, rig, supply, waste and sewage disposal, and pollution prevention. · Vicinity and location plats. RECEIVED FEB 0 1 1982 A DIVISION OF EXXON CORPORATION Alaska 011 & Gas Cons. Corem;ss[on Anchorage C. V. Chatterton Page Two We plan to begin operations approximately February 15, 1982. If you have any questions, please call. Very truly yours J. A. Staffeld CMR:rms 210B/KK 295-666-100 cc: North Slope Borough, Attn: Shehla Anjum Department of Minerals and Energy Management, Attn: Bill Van Dyke ,~"-, STATE OF ALASKA ~ ALASKA L',L AND GAS CONSERVATION CC...MISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work. DRILL [] REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY:~] DEVELOPMENT OIL [] DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE [] 2. Name of operator Exxon Corporation 3. Address Pouch 6601, Anchorage, Alaska 99502 4. Location of well at surface FEB 0 1 i98: 305' WEt 1169' NSL. Sec. 2~ T10N-R23E U.M. 3846' ~ 1169' NSL Tract ~ 114 Attopofproposedproducinginterval A]~k~Oil& GasCo.$,C, 5600' EWL 1900' SNL Tract BF 114 Anchorag~ At total depth 5794' EWL 1414' SNL Tract BF 114 5. Elevation in feet (indicate KB, DF etc.) / 6. Lease designation and serial no. +~.0' Mean Sea Level (ground) ADL 312866 9. Unit or lease name Alaska State D ii]i~ij~O!t~ u tuber Exxon No. 2 11. Field and pool Wildcat 12. Bond information (see 20 AAC 25.025) Dmerican Insurance Co. Type Oil & Gas Conservati~)lqetyand/ornumber 520888.5 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 50 mi.E of Deadhorse/ni[~k. 1169' NSL of lease feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 15000 ' MD 13900' TVD feet 4935.47 19. If deviated (see 20 AAC 25.050) ] 20. Anticipated pressures KICK OFF POINT,-'., 4050 feet. MAXIMUM HOLE ANGLE 35°](see20AAC25'035 (c) (2) 21 Proposed Casing, _iner and Cementing Program SIZE Hole I Casing 40- ]30- 26" {20" 17-1/~" 13-3/ 12-1/~," 9-5/ 8-1/21' 7" Weight 1" WT 133 " 72 " 43.5 Amount $200,000.00 15. Distance to nearest drilling or completed 18. Approximate spud date 2/15/82 8 7 0 ] psig@ Surface 1.].2j13____psig@ ~ft. TD (TVD) 29/32/2 22. Describe proposed program: l. 2. 3. 4. CASING AND LINER Grade I Coupling ~-55 l Butt L-80 I Butt P-110 / LTC 5P-110 ~ LTC Length SE I I lNG DEPTH MD TOP TVD 80 2056 3998 10630 15000 TVD 0 8800/lZ MD BOTTOM TVD I I 11 I 2056 I 3998 1063~ 10000 800/13900 QUANTITY OF CEMENT (include stage data) Permafrost to surfac~ Approx TOC 3100' Approx TOC 8000' 500' Above Potential .... z,,?oo' ,. MD -9290/12650/15000 ¥~Od' HC. zone.. cut and recover 9-5/8" Casing from h~laska~ State D Exxon No. 1 well to approximately 4150'. Set cement plug from aPproximately 1~4~ to 3800'. Drill out.~to 4050' sidetrack from the Alaska State D Exxon No. 1 well and directionally drill to proposed target. Drill a 12-1/4" hole into the pressure transition zone, run and set 9-5/8" casing. Drill an 8-1/2" hole through objectives to total depth. Run and cement 7" casing, bringing cement ~00' above any potential hydrocarbon zones. Blowout Preventor: A 13-5/8", 5,000 psi WP annular BOP and three 13-5/8", 10,000 psi WP ram type preventers will be installed on the 13-3/8" casing as shown on the attached sketch, and will be used along with a 10,000 psi WP choke manifold during drilling and we~l testing. BOP installation and testing will be in compliance with revised Alaska State Regulations effective April 1981. Surface pressures will never be allowed to exceed the design working pressure of the 5000 psi annular preventer. If drilling progresses so that Exxon can demonstrate the ability to operate safely, and ice conditions justify, a request will be made for state authorization to continue drilling and downhole operations until May 15, 1982, as per State Lease Stipulation No. 9. Any changes in State Lease Stipulation No. 9 may affect proposed drilling times. .. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED ~ P~_/~_~¢~%, .~~/ TITLE The space below for C~u~e .... Samples required ES []NO Permit number .APPROVED BY Form 10-401 Rev. 7-1-gQ CONDITIONS OF APPROVAL . Mud log required ~S r-]NO Approval date Directional Survey required I APl number )~YES •NO { 50- 0~19-20015-03_ SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMM ISSI ON ER by order of the Commission DATE Submit in triplicate Alaska State D Exxon No. 2 Collapse - Considers surface pressure = 0 psi, internal fluid weight 8.33 ppg, and external fluid weight 12.5 PPg Maximum Collapse Pressure (MCP) MCP = (External fluid gradient - internal fluid gradient) casing depth - surface pressure = (12.5 x .52 - 8.33 x .052) 10,000' - 0 = 2,168 psi Minimum Exxon Safety Factors Burst 1.312 Collapse 1.00 Tension 1.50 PRODUCTION 7" @ 13,900' ® Burst - Considers shut-in gas well surface pressure and formation pressure of 15.5 ppg. Casing Design Surface Pressure (CDSP) CDSP = (Max. anticipated formation pressure - gas gradient) casing depth = (15.5 x .052 - 0.18) 13,900' = 8,701 psi Collapse - Considers surface pressure = 0 psi, internal fluid weight = 0 ppg and formation pressure = 15.5 ppg Maximum Collapse Pressure (MCP) MCP = (Formation pressure - internal fluid gradient) casing depth - surface pressure = (15.5 x .052 - 0) 13,900 - 0 = 11,203 psi Exxon Minimum Safety Factors Burst 1.312 Collapse 1.125 Tension 1.50 Maximum Anticipated Surface Pressure 8,701 psi Maximum Anticipated Bottom Hole Pressure 11,203 psi RECEIYEi) FEB 0 1 1982 Alaska 011 & Gas Cons. Comm[ss[or~ Anchorage Alaska State D Exxon No. 2 SUBSURFACE INJECTION: The 20" Conductor has been set below any possible freshwater sands and the 13-3/8" casing has been set at 3998' into major gravel zones. After setting the 9-5/8" casing into the pressUre transition zone (10,000), waste fluids and hydrocarbons will be injected into saltwater zones from 4000' to 7000' down the 13-3/8" x 9-5/8" annulus. CASING DESIGN CRITERIA: See attached Wellbore Sketch for design Surface - 13-3/8" @ 4000' Burst - Considers gas gradient to the surface causing lost returns at the shoe assuming maximum expected leakoff gradient. External fluid weight 9.0 ppg. Casing Design Surface Pressure (CDSP) CDSP = (Max. shoe leakoff gradient.- gas gradient) casing depth = (16.0 x .052 - 0.10) 4000' = 2,928 psi Permafrost Freezeback - 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) 2500' = 2,~30 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. Exxon Minimum safety Factors Burst 1.312 Collapse 1.00 Tension 1.50 PROTECTIVE 9-5/8" @ 10,000' 0 1 ]982 ~Jaska Oil & Gas Cons. Commis$iort Anchorage 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. Casing Design Surface Pressure (CDSP) CDSP = (Max. shoe leakoff gradient - water gradient) casing depth = (19.0 x .052 - 8.33 x .052) 10,000' = 5,548 psi CONTINGENCY PLAN ALASKA STATE D EXXON NO. 2 The objective of this plan is to outline major operating and contingency requirements t.o ensure a safe and efficient operation throughout the drilling activity. LOCATION The barrier island location was designed to accommodate the drilling rig, camp, and necessary supplies for a winter drilling operation. The location, which is enclosed with sheet piling and has a freeboar~ of 7 feet, is designed to resist ice override and i.s above the maximum indicated tide based on observations along the surrounding coast. The sheet piling will also provide erosion protection during summer storms. Based on the status of the well and ice conditions existing just prior to March 31, a request may be made at that time to continue drilling operations to no later than May 15. Otherwise, the_rig and associated equipment will be placed on a standby status until remobilization during the summer of 1982 for drilling operations in the fall of 1982. Any changes in State Lease Stipulation No. 9 may change proposed drilling times. POLLUTION CONTROL The location and operating plan will be designed to provide containment of all drilling operation effluents that could be considered as pollutants. An impermeable sheet will be placed under the drilling rig.to collect and divert any liquid waste for proper disposal. Fuel will be stored in welded steel tanks located within an impermeabl~ lined ~rea. Sewage and kitchen waste water will be processed through a State approved biological treating system with excess sludge being incinerated and the disinfected liquid contained in a steel holding tank. Treated effluent may be used as drill water, if needed, with excess being injected as described below. A separate insulated steel holding tank will be provided to store the treating plant effluent in the event of a system malfunction. A flare pit will be located clear of the rig to permit burning of gases and emergency burning of liquid hydrocarbons resulting from well testing. A primary feature of the drilling plan will incorporate the 13-3/8" x 9-5/8" annulus for annular injection. The well casing program for Alaska State D Exxon No. 1 will be utilized. The 13-3/8" surface casing was set into major gravel sections. The 9-5/8" protective casing will be set into the anticipated pressure transition zone and cemented to isolate the saltwater sand sections from below the surface casing shoe to approximately 8,000 feet for injection of lube oil, excess mud, melt water, waste_w~¥~and FEB 0 19 )2 Oil & Gms Cons. Commi~io~i /~chomge -2- well test liquids. The reserve pit will be maintained at a minimum level at all times to provide for containment of well fluids in the event of an upset. All pits will be pumped out to a minimum level and waste water injected into the injection zone before abandoning the location. The entire operation is planned so that no hazardous fluids associated with the operation will be discharged on the surface outside the location. Additional precautions will be taken to prevent drainage of hydrocarbons to the sea. After freezeup, the surface of the island was sprayed with water to form an impervious ice seal. This should 'prevent liquids spilled on the surface from draining downward into the gravel fill. Also, any spills will be cleaned up as soon as possible. Snow contaminated by toxic substances will be incinerated on site or hauled to a State approved disposal site in Deadhorse. The island surface will be thoroughly cleaned after clearing the island of all drilling equipment. The drilling contractor has developed a comprehensive site specific SPCC plan to prevent pollution as a result of any drilling rig operation. In addition, Exxon has a site specific Oil Spill Contingency Plan which outlines responses to spills of any size which might occur. In addition to the impermeable sheet under the rig mats, drip pans and other containment measures are provided under the engines and rig machinery. Good housekeeping will be stressed on all parts of the location with emphasis on minimizing contamination of the peripheral drainage from the island. An on-site oil spill cleanup crew has been designated within the drilling crew. These personnel were~given instruction in the prevention and initial control of oil spills. Most minor operational spills of oil will be collected with sorbent material and disposed of by incineration. Equipment and material, which is listed in the SPCC Plan, will be kept on location for the purpose of building containment dikes and berms, for containing oil spills reaching the water, and for oil spill cleanup and disposal. If required, additional personnel and equipment can be rapidly mobilized from either oil spill contractors or through the Alaskan Beaufort Sea Oil Spill Response Body (ABSORB) Organization, of which Exxon is a member. For spills beyond the capability of the on-site cleanup crew to contain or clean up, the Exxon North Slope Oil Spill Response Team, as outlined in the Exxon North Alaska Oil Spill Manual, will be activated to the degree required by the severity of the spill. WELL CONTROL AND PERSONNEL SAFETY Personnel safety and well control are the uppermost factors in well design and operatiOnal planning. Sufficient data are available to plan the well for evaluation of the geologic objectives, provide for subsurface disposal of waste water, and conduct a safe drilling operation. Exxon and key contract supervisory drilling personnel will be experienced.in well control detection and procedUres and RECEIVE FEB 0 ! 1982 Alaska Oil & Gas Cons. -3- will be graduates of a certified well control school. Abnormal pressure technology will be used to predict and detect changes in formation pressure to permit adjusting the casing and drilling fluid program to control the well. Emphasis will be placed on well control procedures and equipment to permit circulating out a formation influx in an orderly manner if it sh6uld be necessary. Any hydrocarbons in the influx will be diverted to the reserve pit and either burned or later injected into the annulus. In the unlikely event of an unplanned upset ~resulting in uncontrolled well flow, the following basic procedures will be followed: · Divert well flow to the reserve pit as the first defense against a spill. When the safe working level of the pit is reached, switch the flow to the surrounding ice. After the well is under control, produced well fluids will be disposed of by injection into the annulus. The contaminated ice and snow will be cleaned up and incinerated or hauled to an approved disposal site. The capacity of the reserve pit will be maintained at a maximum, practical working capacity at all times by keeping mud and fluid levels at a minimum and pumping fluids into the injection annulus when possible. · Finalize plans for drilling a relief well from previously determined available locations specified in the site specific Oil Spill Contingency Plan. Site selection will be strongly influenced by the bo%tom-hole location of the flowing well at the time of loss of control. · Ignite well fluids at the wellhead, if the situation warrants, only after discussion with proper governmental agencies and Exxon management. Major supplies of mud, cement, casing, fuel, and miscellaneous supplies will be transported over winter roads or flown directly to location-prior to breakup. After breakup, if required, light consumables will be transported by helicopters. Tubulars and wellheads, along with gravel for preparing a relief well location, will be maintained at a suitable location in the area. In the extremely unlikely event of an out-of-control well, both the Exxon North Slope Well Emergency Response Team and the North Slope Oil Spill Response Team, as outlined in the previously mentioned Exxon North Alaska Oil Spill Manual, will be activated. The Well Emergency Team will be responsible for performing all well control functions which includes all surface well control procedures, as well as plans for rapid implementation of an appropriate relief well plan. The Oil Spill Response Team will be responsible for taking immediate action to minimize environmental damage and to institute cleanup operations as required. The Exxon North Alaska Oil Spill Manual contains detailed oil spill scenarios, detection, containment, and cleanup information. RECEIVED FEB 0 1 1982 Oil & Gas Cons. CommJs=io:~ Anchorage -4- An outline of a relief well plan is contained in the site specific Oil Spill Contingency Plan for the well. The basic plan involves construction of a location and drilling a directional well designed to penetrate the flowing zone near the original wellbore. RMB/CMR:se 210C/B RECEIVED FEB 0 ! 1982 Oil & Gas (:or~$. Commissio~ Anchorage T~NK · S0OO pst W.P. ANNULAR BOP RAM BOP Ptpe 10,000 pst V.P. RAM BOP BltndlO.00O pst W.P. Pipe lO,OOO psi W.P. / o .~.~ ~ Sc.~ev~-..~ug--.~::-.Gtt~.. Valve - size p~ovlded vtth A-section Sceewed/~ug VMye - ~" stze' 3, S. 6. 1'1. · ' ' :ICHOK£ _ Screwed Tapped Bullplug wtth tieedle Valve and Pressure Gage - · - Irlm Pl'ue n " ' - 2" size rovtded with wellhead noed r w...r:,,: Yalv, P ~n~d P'iu=-.:~/~:'~. "stze wlth ~o~anton.flange to protect valve flange face Fl'thUd Pl~:-:~:::~te Valve - ~" mtntm~ size . .. :... F)an~ Hyd~Ti:catly Controlled Gate Valve - 3" (~0,000 ps~) ~ .... . .. Flanged Fla~ Type Check Valve * 3" (~0,000 ps~) ' Flanged PT~:"' Va)~:" .... ....:., 4 -" mtntmum size. 5a~e vasve not ToP of ~ular P~ter must ~ equipped wt%h an:..AP] Flange Ring Gasket. All flange. .. studs ~t ~ tn place. The I,D,.':.~? t~:."~ll Nipple ~st not be less than the minimum I,D. of the BOP Stack. ~T~: AT1 val~:::~ kill and choke lines ID,ODD psi W.P. ALASKA STATE"D" EXXON --. RECEIVED' FEB 0 1 1982 Oil & Gas Cons. Commissio~l Anchora,q~ WELLBORE AND CASING DESIGN SKETCH ALASKA STATE D EXXON NO. 2 30" Conductor @ 110 ft 20" 133 lb/ft K55 BTC Conductor @ 2056 ft TOC approximately 3100 ft 13-3/8" 72 lb/ft L80 BTC Surface Casing @ 3998 ft Waste Fluid and Hydrocarbon Injection Zone TOC approximately 8000 ft TVD 8300 ft MD 9-5/8" 43.5 lb/ft ?110 LTC Protective Casing @ 10,000 ft TVD 10,630 ft MD TOC 500 ft above any potential Hydrocarbon Zone 7" Production Casing @ TD 13,900 ft TVD 15,000 ft MD FROM TVD ft MD ft 0 0 8,800 9,285 11,800 12,'640 Casing 7" 29 lb/ft Pll0 LTC 7" 32 lb/ft Pll0 LTC FEB 0 1 1982 Oil & Gas Cons. CommJssio,,I Anchorage NOTE~ 100 WELLBORE SEPARATION FT j TVD FT 800/- 6203 600 / 5856 4OO 5OO / 300/ 5325 / 200 ¢. 5100 / / / 4800 ALASKA STATE D-2 ALASKA STATE D-1 SURFACE LOCATION STRAIGHI' HOLE D-1 wellbore is headed in a southeasterly direction at D-2 k~ckoff point. I 5683 / 5510 SIDETRACK KOP ,4OSOFT RECEIVED FEB 0 1 ]982 Ala,~ka 0il & Gas Cons. Commissio. Anchorag9 ALASKA STATE D EXXON NO. 2 WELLBORE SEPARATION VS. TVD 1/27182 1"=100' ALASKA STATE D-2 LONG 146° 12' 2 5. ,56" ¢~,~,~ 5, Proposed Bottom Hole ~e~ufor/ j Sea / See Detu/'l For Locution Wi'thin BF 14 1 28 Z7 26 29 PT THOMSON ~ ~ _~ I/g ~ ~ '~'"~ T I0 N NIW ~ ~ TOPO FROM FLAXMAN IS, (A-4), AK USGS T. ION, R.ZSE,UM FPROPOSED D-2 BHL SCALE I"= I MILE ~ REVISED Bottom Hole Location 1/25/82 14 ~~ I~REViSED for D-2 Well Locution ~ Bottom Hole I/1~ Surfoce cation ~ REVISED Surfoce Locotion ~{5/81 ALASKA STATE / I PROPOSED WELL LOCATION / VED' ALASKA STATE D-2 SURFACE ~~ i ll69' ~ 305' i o DETAIL LO CATE D IN SECTION. ~3, T ION~ R23E~U.M. , CERTIFICATE OF SURVEYOR NaskaOii&Gas~ ODS. COmmiSSiON FOR I ~reby ~rtify that lam prop~ly registered and licensed~ch rage to ~actice land surveying in the Stafeof Ala~a and that this EXXON COMPANY U.S.A. plat represents alocationsuwey made by me or under my direct supervision and that all details are correct. BY z-~.-~o ~ ~ BESSE, EPPS ~ POTTS DATE '~DRVEY~ ' / / ANCHORAGE~ALASKA 344-1352 EE ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA g9502 EXPLORATION DEPARTMENT OFFSHORE/ALASKA DIVISION February 1, 1982 Re: Exxon Alaska State "D" No. 2 Section 14, T9N, R23E, UM ADL 312866 Arctic Slope, Alaska Mr. William Van Dyke Petroleum Manager Division of Minerals and Energy Management Pouch 7-005 Anchorage, Alaska 99510 Dear Mr. Van Dyke, Exxon Corporation has filed an application with the Alaska Oil and Gas Conservation Commission for a permit to drill and the contingency plans for the captioned well with our check for the amount of $100.00 in payment of the required permit fee. We are submitting the following in accordance with requirements of the captioned oil and gas lease and regulations: A plan of operations for the proposed well describing the drilling pad, rig supply, waste and sewage disposal and pollution prevention. Two area operations maps for the proposed well: - Area map of, Scale 1" = 10,000 ft, showing sea' ice road, rolligon haul routes and the relationship of the proposed well to those in the Duck Island and Point Thomson areas. - Location and well pad layout of scale 1" - 30 ft. Survey plat, of scale 1" = 1 mile with X and Y coordinates as well as latitude and longitude. RECEIYEI) A DIVISION OF EXXON CORPORATION FEB o 1 1962 Oil & Gas Cons. Commission ' Anc.~orage William Van Dyke Page Two We plan to begin operations approximately February 15, 1982. If you have any questions, please call. Very truly yours, J. A. Staffeld CMR:rms 210B/LL 295-666-100 Alaska Oil and Gas Conservation Commission, Attn: C. V. Chatterton Alaska Dept. of Environmental Conservation, Attn: Douglas Lowery Alaska Dept. of Fish and Game, Attn: J. Scott Grundy Division of Forest, Land and Water Management, Attn: William Copeland North Slope Borough Attn: Shehla Anjum RECE VED FEB 0 1 1982 0il & Gas Cons. commJssio[~ Anchorage " EXXON COMPANY, U.S.A. PLAN OF OPERATIONS EXXON ALASKA STATE "D" (ADL'312866) WELL NO. 2 General This well will be drilled directionally from the No. 1 wellbore which is located 305 feet WEL,. 1169 feet NSL, Section 23, T10N, R23E, U.M. The surface location of the wellbore is also 3846 feet EWL and 1169 feet NSL of Lease Tract BF 114. The drill site is on the west end of Flaxman Island in the Beaufort Sea about 50 miles east of the Prudhoe Bay East Dock. This site was constructed during the winter of 1980-81. Well No. 2 will be spudded about February lS, 1982 and will require approximately five months for drilling and testing. Arctic Alaska Drilling Co. Rig No. 4, previously used to drill Alaska State "D", Well No. 1, will also be used to drill this location. Logistics Access to the proposed location during the winter of 1981-82 and possibly 1982-83 will be provided by a sea ice road along the shoreline of the Beaufort Sea extending from Prudhoe Bay East Dock to Point Thomson No. 3 and continuing in a northerly direction to the location. 'An additional ice road may also be required from Point Thomson No. 3 to an alternate water source near Alaska State C-1. These road routes are shown by Exhibits "A" and "B" which are attached. Additional supplies for drilling operations will be transported to the drill site by barge from Prudhoe Bay during the open water season of 1982. After freeze up begins, helicopters or state approved land vehicles will be.used for t~e movement of supplies until an ice road can be completed. Most personnel will be transported by helicopter and possibly air cushion vehicles prior to the completion of the ice road. Traffic will be routed to avoid waterfowl nesting and staging sites. An ice landing strip, approximately 2000 feet long, will be constructed to facilitate air transportation during winter opera- tions. During the winter, if bulky equipment must be delivered on short notice or large shipments accumulated, an ocean ice landing strip for Hercules aircraft may be constructed on the sea ice. While drilling, some materials needed for drilling operations will be temporarily stored on the island surface adjacent to the drill site. These include tubular goods, dry mud materials, and vehicles. During summer standby, all materials will be stored on the drill site. REC IVEi) FEB 0 1 1982 Oil & Gas Cons. Commlss!o~ Page 2 Dr illing Operations Drilling operations will commence about February IS, 1982. If drilling progresses so that Exxon can demonstrate the ability to operate safely, and ice conditions justify, a request will be made for state authorization to continue drilling and downhole operations until May 15, 1982 as per State Lease Stipulation No. 9. This plan will be modified in accordance with any subsequent changes in Stipulation No. 9. If the proposed well cannot be completed within the authorized 1981- 82 interval, drilling operations will be suspended. Any remaining fuel and lubricants will be stored on the island during the summer. Additional fuel and supplies will be barged again to the drill site in the late summer of 1982 so that drilling.operations can resume in the fall of 1982. An impermeable plastic sheet is installed under the drilling rig to collect liquid drainage and direct it to the well cellar for recovery and disposal. All pits, except for the flare pit, are lined with an impermeable plastic liner. The'reserve pit will be used only for the emergency storage of excess drilling fluids or small amounts of cement or cement contaminated mud. The wellbore will be designed for annular injection for the subsurface disposal of waste liquids. Water for drilling operations will be obtained from desalination units or hauled from a water source located in Section 14, T9N, R23E near Alaska State "C", Well No. 1. The development and operation of this source was approved by appropriate state government regulatory agencies. A snow melter may also be used to supplement rig water requirements. Potable w~ter will be processed through a state approved water treating unit before use in the camp. Disposal of Waste Materials The following waste material procedures will be observed during drilling operations. After drilling operations are completed, any remaining materials will be promptly removed from the drill site. 1. Drilling Mud will be injected in the~ casing annulus or hauled to a state approved site for disposal. 2. Cuttings from the wellbore will be temporarily stored on the surface of the island adjacent to the drill site and subsequently hauled to a centrally located landfill in the Point Thomson area for disposal. The development and operation of this landfill has been covered by separate permit applications to appropriate government agencies. Construction will commence upon permit 'approval. RECEIVEI) F E B o 1 1982 Gas Cons. Commis=[o!~ An~.hnmfl~ Page 3 3. Sewage Effluent and Gray Water: Sanitary sewage will be treated with a state approved sewage disposal unit owned by Arctic Alaska Drilling Co. Treated effluent from this unit will be Combined with gray water from the camp kitchen and bathrooms in a steel storage tank and used in drilling mud or rig wash water. A steel tank will be provided for the emergency storage of these liquids during upset conditions. Any surplus quantities-of this liquid will be injected in the casing annulus. 4. Domestic Garbage will be disposed of in a state approved incinerator. 5. Combustible Wastes such as paper, wood, and cardboard will be incinerated in the state approved unit or open burned. 6. Noncombustible Wastes such as scrap metal, batteries, drums, wirelines, etc. will be hauled to a state approved site for disposal. 7. Well Test Fluids: Produced gas will be flared. Produced liquids will be injected in the casing annulus or hauled to a state approved site for disposal. 8. Waste Oil will be injected in.the casing annulus or hauled to a state approved site for disposal. Surface Protection and Restoration Plan Surface transportation to the drill site will be primarily over ice roads during the winter or by barge during the summer. Roll igons or other approved vehicles may also be used in the spring and fall. Special procedures for drilling and subsurface equipment are required by the unique characteristics of the permafrost area. Casing cement used through the permafrost zones is of special composition to reduce possibility of freezing and other casing problems. Casing is run and cemented through the permafrost, and in the event of production or interruption of operation, the uncemented casing must be protected by the use of non-freezing fluid. At the completion of the well, the location and adjoining area will be cleared of all waste materials. ECEIVE. D FEB 0 1 1982 0;I ~' Gas Cons. Page 4 Velocity Survey A velocity survey will be made prior to the completion of the well. In this procedure, holes will be drilled in the sea ice along the surface projection of the wellbore path, and an airgun or a Vibroseis unit will be used as the energy source for the survey. If the Vibroseis unit is used, it will not be necessary to drill the holes in the ice along the wellbore path. An alternate method which may be used will utilize a 40-inch diameter cased hole, 40 foot deep, located on the drill pad near the wellbore. The hole will be filled with brine just prior to the survey in which an airgun will be used as the energy source. A further alternative, in the event that neither of the above provide satisfactory data, will be the use of a 10 foot diameter tank, 20 foot high, which is filled with water. An airgun will also be used in this survey as the energy source. Natural Environment Drill Site Construction Development Plans The above topics were fully covered by the Plan of Operations for Exxon's Alaska State "D", Well No. 1 which was previously approved by the Division of Minerals and Energy Management letter of February 18, 1981. These discussions apply equally to the well covered by this plan as it will be drilled from the same site as used for Well No. 1. AVL: 1 j m 1-19-82 '28 / 27 32 5794` / PROPOSED ALASKA STATE D-2 LAT. 70° 12' 09.32_" LONG 146° 12_' 25.56" y- 5~923,678 x - 474,307 .~~ Proposed Bottom Hole / See Defa/I For ~e au for / { TOPO' FROM FLAXMAN IS. (A-4), AK USGS /-PROPOSED D-2 BHL SCALE I"= I MILE / 1 ~- REVISED Bottom Hole Location 1/25/82 {17o9'~,/ IREVISED Bottom Hole Location 1/19/82 for { /I 2/82 I~-:~./~,, i3 IREViSED D-2 Well Location ~ Bottom Hole Surface I 24 REVISED Location 3/26/131 REVISED Surface Location / / IrED,,o,os o --~os' ALASKA STATE D-2 1 1982 LOCATE D IN SECTION. 23, T I0 U.M. S~O~ FO R 0rag~ EXXON COMPANY U.S.A. FEB( DETAIL C E R T I F I CAT E 0 F S U R V EY 0 R ~l~ka Oil & Gas I hereby certify that lam properly registered and licensed /-uriCj to practice land surveying in the Steteof Alaska end that this plat represents (] location survey mede by me or under my direct supervision end th~ oll details ere correct. 7-24 -80 ~ DATE '§OR V EYo~ ' / / BY BESSE, EPPS 8~ POTTS ANCHORAGE A KA 344-1352 33 D-2 SURFACE ,,69' '23 ALASKA STATE T. ION, R.Z3E,U M 14 L ~e4e '/ ~/ Locol../o_n ~/l'~hl'n B F 114 ~~ ..... ,,~. . ,~, e c t/Or/ I i r i - CHECK LIST EOR NEW WELL PERMITS Comp a ny IT~ APPROVE DATE (1) Fee (2) Loc thru (3) Admin(4 thru 11) i · · 3. 4. Is well located proper distance from other wells .................... z~ 5. Is sufficient undedicated acreage available in this pool ............ ~ 6. Is well to be deviated and is well bore plat included ............... 7. Is operator the only affected party ................................. ~ 8. Can permit be approved before ten-day wait ..- ................... · .....z .... (4) Casg 2~~thru 20)~'k~-~-z'~ 9, 10. 11. 12. 13 14. 15. 16. 17. 18. 19. 20. YES NO REMARKS Is the permit fee attached ............................. ' ........... .~,, Is well to be located in a defined pool ........................... ~.~×, ~~ Is well located proper diStance from property line .................. ~~--- ru 24) 22 23. 24. (6) Add:~ Does operator have a bond in force . .~ .... .... Is a conservation order needed ........................ Is administrative approval needed ....... ' Is conductor string provided ................. ......... .....,: .' .... [~"~~Y~ ~J~~ Is enough cement used to circulate on conductor and surface~i ! ' Will cement tie in surface and intermediate or production s - Will cement cover all known productive horizons ,.... ...... W±ll surface casing protect fresh water zones .............. Will all casing give adequate safety in collapse, tension.an, cl, b.u..r:t!.~_~: '~ Is this well to be kicked off from an existing wellbore . Is old wellbore abandonment Procedure included on 10-403 Is adequate well bore separation proposed ..... · ............ Is a diverter system required ........... .......................... ,. ~__~ Are necessary diagrams of diverter and BOP equipment_attached _.~.. Additional requirements ............................................. c) ~Z Ge ology: Engin~e~q~ ~ng: ~ JKT WVA ~TM ~AD ~ rev: 01/13/82 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ,, ,