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Home My WebLink About193-078Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. 1<~ ,.~ "07~ File Number of Well History File PAGES TO DELETE Complete RESCAN n Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: Other- Pages: DIGITAL DATA Diskettes, No. Other, No/Type OVERSIZED .El El Logs-of various kinds Other COMMENTS: Scanned by: , Beverly~~ncent Nathan Lowell TO RE-SCAN Date: ,, Is/ Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03 2001 PL W M ATE IA L U N D E~ TH IS M ARK ER ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HIGKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276.7542 January 10, 1994 Paul Mazzolini ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Dear Mr Mazzolini: The Commission is compiling statewide drilling statistics for 1993. Attached is a list of outstanding Permits to Drill issued to your engineering group (permits for which no form 10-407 has been received by this office). Please review this list to determine if any of the wells were drilled in 1993. If so, please note the well name, total measured depth, and class (development, service or exploratory). If any wells were drilling as of.12/31/93, estimate the depth at 12:00 midnight. We would appreciate your reply by the end of January if possible. Thank you for your cooperation with this project. If I may be of any assistance, please call me at 279-1433. Yours very truly, Robert P Crandall Sr Petr Geologist encl jo/A:RPC:~rlstats ~/04/94 OPERATOR ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA INC 'ALASKA WELLS BY ARCO PERMIT 93-0078-0 93-0095-0 93-0064-0 '93-0066-0 WELL NAME NORTH FORELAND ST 2 S COOK INLET ST 1 S COOK INLET ST 2 S COOK INLET ST 3 PAGE 1 ALASKA OIL AND GAS CONSERVATION COMMISSION April 25, 1994 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 James Trantham ARCO Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: BOPE testing ARCO-Phillips North Foreland//2 Dear Mr. Trantham: In your March 22, 1994 letter to Mr. Wondzell, you proposed alternative methods for testing BOPE equipment for the ARCO-Phillips North Foreland #2 well. The BOPE testing requirements of 20 AAC 25.035 do not provide for alternatives. Variances can be granted only by conservation order, following public notice and opportunity for comment. Should ARCO still wish to pursue its proposed changes for North Forelands #2, please submit a formal application with supporting information. Please note that 20 AAC 25.035 provides for both pressure tests and function tests of BOP equipment. Under 20 AAC 25.035(a)(6), blind rams must be function-tested each trip and all other BOPs each day. Thus, it is unclear how your test scenario #2 could be considered an improvement. Chairman ARCO Alaska, Inc. (i ~ Post Office Box-100360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 March 22, 1994 Mr. Blair Wondzell, P.E. Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 VIA FACSIMILE: 276-7542 Re: BOPE Testing Intervals Permit to Drill (Permit Number 93-78) ARCO-Phillips North Foreland #2 (NF #2) Dear Mr. Wondzell: In reference to Commissioner Johnston's letter dated February 18, 1994 concerning BOPE test intervals, please accept this letter of clarification. ARCO is not seeking a modification to the state- wide regulations. ARCO is requesting an alternate method of testing our BOPE on the above referenced well. ARCO proposes to pressure test the BOPE on an "alternate week schedule" and function test certain components of the BOPE weekly. Below are descriptions of the two alternating test scenarios: Test Scenario #1 - Initial Installation and alternating week after Test Scenario #2. All BOPE (except the annular preventer) will be tested to the rated working pressure on the initial test or to the maximum surface pressure as required to be submitted in (d) (2) of 20 AAC 25.035 on subsequent Scenario #1 tests. Low pressure tests (and testing the ram locks) are incorporated in this test. The annular preventer will be tested to not less than 50 percent of the rated working pressure. Test Scenario #2 - Seven days after Test Scenario #1 with no equipment/component change The choke/kill manifold, along with the IBOP and Safety Valve, will be tested to the rated working pressure or to the maximum surface pressure as required to be submitted in (d) (2) of 20 AAC 25.035. Low pressure tests are incorporated in this test. The pipe rams and annular preventer will be function tested on drill pipe during the trip. The blind rams will be function tested while the drill string is out of the hole. Kelly valves will also be function tested. Please note that the inspectors will have the option of witnessing either of the tests during their inspection tours to the rig. The alternating test scenario will achieve and improve upon the recommendations stated in RP 53 (7.A.7)by performing a "full" test every 14 days instead of the recommended "no less than once every 21 days". We hope the information we have provided you since the correspondence of Commissioner Johnston is sufficient to help you make a determination on our proposal. If you have questions, please contact me at 265-6434 or Paul Mazzolini at 265-6112. Thank you for your attention. Sincerely, JaYmes Tr~ntham ' Cook Inlet Drilling Engineer ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company RECEIVED MAR 2 4 1994 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. rI' Post Office Box luu360 Anchorage, Alaska 99510-0360 Telephone 907 263 4614 D. J. Ruckel KRU/CI/NV Drilling Manager February 8, 1994 D. W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: BOPE Testing Intervals Permit to Drill (Permit Number 93-78) ARCO-Phillips North Foreland ~ (NF #2) Dear Commissioner Johnston: ARCO Alaska, Inc. hereby requests an exemption pertaining to 20 AAC 25.035(7)(A) for the 1994 drilling season in the Cook Inlet. The regulation states "These tests must be made when the BOPE is installed, or changed, and at least once each week after that." ARCO Alaska, Inc. is asking for the testing intervals of the Blowout Preventers to be extended from a one week to a two week interval during drilling and testing operations. Our proposed exemption would be interpreted as "These tests must be made when the BOPE is installed, or changed, and at least once each 14 day period after that." To further clarify our intentions, the following table explains the effect of an exemption on BOPE testing. Present Testing Proposed Testing Pressure test to working pressure upon nipple up Test interval not to exceed 7 days Pressure test prior to drilling out each casing string Blind/shear rams functioned each trip Testing following disconnect or repair of pressure seals Variable Bore Rams tested on both drill pipe sizes Pit drills performed weekly Sanle Test interval not to exceed 14 days Sallle Same Same SalTle Same ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company RECEIVED FEB 1 0 1994. Alaska Oil & Gas Cons. Commission Anchorage D. W. Johnston, { .irman ? February 8, 1994 Page 2 This request was addressed in your January 24, 1994 meeting with Mr. Blair Wondzell and Mr. James Trantham. We supplied data prior to the meeting which established the fact that there is a trend world wide supporting 14 day BOPE test intervals. The trend is supported by independent research of BOPE test data. The MMS is currently allowing 14 day test intervals in the Gulf of Mexico. The data we presented at that meeting pertained to our drilling efforts in the Cook Inlet. The Adriatic vm, which is owned and operated by Global Marine Drilling Company, will be the drilling contractor for ARCO Alaska, Inc. this year in the Cook Inlet. Our data of the Adriatic VI/I exhibited a very low frequency of failures during the 1993 drilling season. The failure rate of the Adriatic VIII components were less than rates noted for drilling and work-overs in the Gulf of Mexico. The failures experienced in the 1993 drilling season would not have compromised secondary well control (primary well control being drilling fluids). Global Marine's preventative maintenance program on the Adriatic VIII Blowout Preventers, combined with non-corrosive drilling fluids, is the reason for such a low incident rate. Recently, Global Marine Drilling Company performed preventative maintenance as indicated by the preventive maintenance schedule that was provided at the meeting. Please note that on June 15, 1993, ARCO Alaska, Inc. received a Permit to Drill the North Foreland #2 well. It is our intention at this time to drill this well during the 1994 drilling season. Therefore, if this exemption is granted it would be applicable to the North Foreland #2 well. We appreciate the assistance we have received from Mr. Wondzell on this matter. If you have questions pertaining to this request, please contact James Trantham at 265- 6434 or Paul Mazzolini at 265-6112. Thank you for your attention. Sincerely, Douglas J. Ruckel RECEIVED FEI3 1 0 1994 Alaska Oil & Gas Cons. Commission Anchorage ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HIGKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276.7542 June 15,1993 Paul Mazzolini, Sr Drlg Engr ARCO Alaska, Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Well # Company Permit # Surf Loc Btmhole Loc North Foreland St. #2 ARCO Alaska Inc 93-78 3279'FNL, 1700'FEL, Sec 22, T11N, R10W, SM 3279'FNL, 1700'FEL, Sec 22, T11N, R1 OW, SM Dear Mr Mazzolini: Enclosed is the approved application for permit to drill the above referenced well. Your application for a variance t° the setting depth of casing required by 20 AAC 25.030(c)(2) to allow setting 20-inch casing as deep as 2500 feet TVD is hereby approved. For this well Phillips is also exempted from the requirements of 20 AAC 25.065(c) relating to hydrogen sulfide unless hydrogen sulfide is detected during drilling operations.. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W(J,,0hnston Chairman BY ORDER OF THE COMMISSION jo/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALA~r,,A OIL AND GAS CONSERVATION COMMISS~,..,~ PERMIT TO DRILL 20 AAC 25.005 I la. Type of Work Drill X Redrill -- I 1 b. Type of Well Exploratory X Stratigraphic Test Development Oil Re-Entry __ Deepen --I Service __ Development Gas ~ Single Zone _ Multiple Zone 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 200' above mudline feet Wildcat 3'.' Address 6. Property Designation P. O. Box 100360, Anchorage, AK 99510-0360 ADL 381217 (ALK-4645) 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 3279 ' FNL, 1700' FEL, SEC 22, T11N, R10W, SM N/A Statewide At top of productive interval 8. Well number Number ARCO-Phillips SAME North Foreland St.#2 #U630610 At total depth 9. Approximate spud date Amount 3279 ' FNL, 1700 ' FEL, SEC 22, T11N, R10W, SM ~/9-~/93 ,~.~,,4'~. $200,000 12. Distance to nearest 13. Distance to nearest well 14. 'Number of acres in property 15. Proposed depth (MD and TVD) property line NF #1 15050' MD RKB 17oo' @ surface feet 2 mile at surface feet 3840 15050' TVD RKB feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth N/A feet Maximum hole angle N/A Maximum surface 2636 psi~ At total depth (TVD) 15050 tt 18. Casing program ~ Setting Depth size Specification~ Top Bottom Quantit)/of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include sta~le data/ Driven 30" 457# B D-60 253' 47' 47' 300' 300' N/A 17.5" 13-3/8" 72# N-80 BTC 2453' 47' 47' 2500' 2500' Lead 4960 cf, Tail 575 cf 12.25 9-5/8" 53.5# L-80 BTC 9703' 47' 47' 9750' 9750' Sufficient to cover all H.C. 8.5" 7" 35# L-80 BTC 15003' 47' 47' 15050' 15050' 1055 cf Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: ' measured feet Junk (measured true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural c'o RECEIVED Intermediate Production LinerMAY 1 9 1993 Perforation depth: measured Alaska 0il & Gas Cons. Commission true verticalAnchorage 120. Attachments Filing fee ~ Property plat ~ BOP Sketch X~ Diverter Sketch ~ Drilling program .~. Drilling fluid program ~ Time vs depth plot ~ Refraction analysis ~ Seabed report __20 AAC 25,050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed'~'~/~ ~/'/~ Title Sr. Drilling Engineer Date ~ (/~ Commission Use Only Permit Number I AP, number I Approva, date J See cover,e,er for ~..~- ~' 50- ~.~ - ,~..~<:3 ~'~ other requirements Conditions of approval Samples required .1(y e s ~ N o Mud log required ~ Y e s~ N o Hydrogen sulfide measures~ Y e s .~. N o Directional survey required ~ Yes ~ N o Required working pressure forBOPE __2M; ~ 3M; __ 5M; .~ 10M; ~ 1 5 M Other: %!)d Copy/ Ortglnal Signed By by order of~,,/Z /L_y' ' /'~' '"'$ Approved by David W. Johnston Commissioner the commission Date Form 10-401 Rev. 7-24-89 ? Submit in triplicate ARCO - Phillips North Foreland #2 CASING SCHEMATIC (All depths RKB) Beluga Fm @6,350' Tyonek Fm @ 9,650' Sunfish Fm @ 13,850' N.Foreland Fm @ 14,350' :.::'.:.::::..':::;:'..:, ::;:'..'.::::;:'....::::,, 30"x 1-1/2" Wall, D-60 Drive Pipe @300' or to refusal Top of Cement @surface 13-3/8",72,N-80, BTC Surface casing @ 2,500' TOC @ 5,850' TOC @9,500' 9-5/8", 53.5#,L-80, BTC Intermediate Casing @ 9,750' RECEIVED MAY 1 9 1993 Alaska 0il & Gas Cons. Commission 7", 35#,L-80,BTCAnchorage Production casing @ 15,050' TD @ 15,050' jt-5/10/93 ARCO - Phillips North Foreland #2 DRILLING PROCEDURE Per 20 AAC 25.005 (c) (10) (All depths are measured from RKB unless otherwise noted) Tow rig from Rig Tenders' Dock to well location and jack down legs. Estimated tow distance is 30 miles. Using leg jacking mechanisms, maintain constant air gap of 1' to 5' through one complete tide cycle. Divers will check the spud cans during the slack tide. Preload will consist of taking on 11,000 Kips (5,400 short tons of Inlet water). After 12 hours at pre-load conditions or after all discernible leg settling has ceased, whichever last occurs, discharge pre-load water and jack up to operating height and rig up to spud. Rig up drive hammer and drive 30" structural casing to refusal (Minimum of 100' BML). Buttweld hanger sub should be positioned about 15' BML. Install 27-1/2" x 37" Diverter on 30" structural casing and function test. Notify Alaska Oil and Gas Conservation Commission (AOGCC) 24 hours in advance of testing the diverter so they may witness if desired. Pick up drilling assembly and clean out conductor. Drill 17-1/2" hole to 2,500' RKB. Run 13-3/8", 72#, N-80, BTC surface casing to 2,500' RKB. Land casing in buttweld sub in 30" drive pipe. Be sure to have space out pups handy. Centralize in 30" casing. Cement 13-3/8" casing to surface. Open cleanout ports at mudline hanger and assure there is no cement in 13-3/8" x 30" annulus above the mudline hanger. If desired, spot water containing a cement retarder in the 13-3/8" x 30" annulus. Close hanger ports. Install 13-5/8" 10,000 psi starting head. NU a 13-5/8" 10,000 psi WP BOP stack. Pressure test BOPE to 10000 psi. Notify AOGCC 24 hours in advance of test so they may witness if desired. Pressure test 13-3/8" casing to 3800 psi (70% of burst). Drill out and perform formation integrity test to leak-off. Drill 12 1/4" hole to 9,750'. RKB with MWD equipment in the string. At 9,750', run the following open-hole logs to 13-3/8" shoe: 1 - -D ITE/LD T/C NL/S onic/AM S 2--CST (Percussion sidewall) - optional REEEIVED MAY 1 9 '199;5 Alaska Oil & Gas Cons. Anchorage Note: 3--VSP (Cased hole) - optional Run 9-5/8", 53.5#, L-80, BTC casing to 9,750' RKB and land in mudline hanger system. Cement 9-5/8" casing to cover all significant hydrocarbon bearing zones as per state regulations. Open cleanout ports at mudline hanger and assure there is no cement in 13-3/8" x 9-5/8" annulus above the mudline hanger. If desired, spot water containing a cement retarder in the 13-3/8" x 9-5/8" annulus. Ensure the 13-3/8" x 9-5/8" annulus is open for annular injection. Close hanger ports. Raise BOP stack, cut off the 9-5/8" casing and install 13-5/8", 10,000 psi x 13-5/8", 10,000 psi casing head. Nipple up BOP stack on casing head and test the wellhead to 4600 psi and the BOPE to 5,550 psi (70% of burst). Notify AOGCC of BOP test. Run cased-hole logs if any from TD to the 13-3/8" casing shoe. Pressure test 9-5/8" casing to 5,550 psi (70% of burst). Drill out and perform formation integrity test to leak-off. Drill 8-1/2" hole to approximately 15,050' RKB. This includes 2-3 60' cores in primary objective sands (Sunfish section), and 1-2 60' cores in the secondary objective sands (North Foreland). At 15,050', run the following open-hole logs to the 9-5/8" casing shoe: 1--DITE/LDT/CNL/Sonic/AMS 2--FMS or FMI/GR/AMS - Dipmeter 3--DSI (Dipole Sonic) ~ optional 4--CST (Percussion sidewall) - optional 5--MDT or RFT - optional If logs indicate further testing of the zones proceed and test as follows: Run 7", 35#, L-80, BTC casing to 15,050' RKB. Cement 7" to cover all hydrocarbon zones. Design the top of cement at the minimum of 250' above 9-5/8" shoe. Open cleanout ports at mudline hanger and assure there is no cement in 9-5/8" x 7" annulus above the mudline hanger. If desired, spot water containing a cement retarder in the 9-5/8" x 7" annulus. Close hanger ports. Raise BOP stack, cut off the 7" casing and install 13-5/8", 10,000 psi x 13-5/8", 10,000 psi casing head. Nipple up BOP stack on casing head and test the wellhead to 7000 psi and the BOPE to 5,900 psi (70% of burst). Notify AOGCC of BOP test. Clean out to the top of float equipment. Run cased-hole logs (casing caliper, CBT) as necessary. RECEIVED MAY I 9 1993 Alaska 0il & Gas Cons. Commission Anchorage Pressure test 7" casing to 5,900 psi (70% of burst). Test using 3-1/2" tubing string by perforating under balanced and flowing up the tubing and through surface testing facilities. Test liquids are to be stored in tanks aboard the drilling unit and pumped back into the reservoir or down the 9-5/8" X 13- 3/8" annulus after testing. Gas is to be flared. Testing will involve alternating flow periods and shut-in periods. Individual intervals may be tested separately or concurrently. After completion of testing, kill well and remove test string and packer. When testing is completed, squeeze all open perforations and abandon well per 20 AAC 25.105. Disengage running tools (MLH) and recover all casing from 15' BML. Cut off 30" casing BML. Jack up legs of drilling unit and remove rig from location. RECEIVED MAY 1 9 199; Alaska 0il & Gas Cons. (;or~missior' Anchorage NORTH FORELAND #2 DRILLING TIME CURVE 0 -1000 -2000 -3000 -4000 -5000 -6000 -7000 -8000 -9000 -10000 -11000 -12000 -13000 -14000 -15000 -16000 -17000 -18000 i_ I"'I I II~G · . North Foreland #1 Actual ;~-.-[:~ ...... ~-,~"'" t'A..... ,. Depth : ~ NF #2 Planned _ ~ ~ ~- ~ ~q --. ............ ~ ................. ~ ........... ~- -- --- ~ I 0 10 20 30 40 50 60 70 80 90 100 110 120 DAYS JT 5/17/93 ARCO - Phillips North Foreland #2 PRESSURE ANALYSIS per 20 AAC 25.005 (c) (7) A pressure analysis was performed for this well using site-specific seismic data and offset well information from wells in close proximity to the planned drilling location. The purpose of the pressure analysis is to predict the potential for over pressured strata based on remote seismic data and specific well information. The closest well to the NF #2 is the NF #1 (drilled to 17,700' TVD). Attached is a graph showing the mud weights used in the NF #1 well and the Sunfish #1 well. The recently completed Sunfish #1 is located about 4 miles to the Northeast. In addition to the specific drilling information gained from these wells (i.e.; mud weight vs. depth and sonic Icg data), a site specific seismic survey was performed and is presented in graphical format. This information was used to compile and submit the Proposed Mud Program for this well. As noted, on the following graph of the North Foreland and Sunfish Mud Weight vs. Depth, we anticipate raising the mud weight to approximately 10 - 12 PPG in the Tyonek formation (_+ 9650'). This is necessary to control hole stability due to the flow of tectonic-stressed coal stringers. The associated sands throughout the Tyonek are mostly normally pressured as experienced in both the Sunfish #1 and North Foreland #1 wells. A sharp pressure transition is expected below the Sunfish formation but prior to North Foreland penetration. The anticipated pore pressure in the Sunfish is 9.8 PPG and 13.5 PPG in the North Foreland. Mud weight will be raised to 13-14 PPG in anticipation of the North Foreland pay expected @ +14,350'. We are currently interpreting a shallow hazards survey and will submit the analysis as soon as possible. R'E EIVED MAY 1 9 1993 Alaska Oil & Gas Cons. ¢ommissio~ Anchorage NORTH FORELAND vs SUNFISH MW -1000 -2000 -3000 -4000 -5000 -6000 -7000 -8000 -9000 -10000 -11000 -12000 -13000 -14000 -15000 -16000 -17000 -18000 ~ __ SUNFISH .... II NF#1 m- j ~l~m m L~ II [~1 "~,L~.~ II -mmmmmmmmmmmm -- 8.00 9.00 10.00 11.00 12.00 13.00 14.00 15.00 16.00, 17.00 .u~,~,,,,,~R ECE iVE D SWR 8/25/92 MAY 1 9 1993 A)aska Oil & Gas Cons. Commission Anchorage 2000 4000 6000 8000 U.I r~ 10000 12000 14000 16000 18000 NF #2 Seismic Dat; 10 100 1000 ITT (ms/ft) II~ E~ E iV MAY 1 9 199~ Alaska Oil & Gas Cons. Commission /~nchorago NF #2-A Siesmic Data 200O 400.0 6000 8000 10000 12000 14OOO 16OOO 10 lO0 1000 Shale ITT (ms/f,~ ~ E(~ E I V E D MAY 1 9 1993 ,Alaska OJJ & Gas Cons. Commission Anchorage ARCO- Phillips North Foreland #2 PROPOSED DRILLING FLUID PROGRAM per 20 AAC 25.005 (c) (6) INTERVAL: HOLE SIZE: CASING SIZE: MUD TYPE: From Base of Drive Pipe to 2500' RKB 17-1/2" 13-3/8" Flocculated Bentonite/Inlet Water System MUD PARAMETERS WEIGHT: 8.5 - 10.0 ppg VISCOSITY: 50 - 100 sec./qt PV: 12- 18 YP: 15 - 30 pH: 9.0 -10.0 FILTRATE: 2 0 MAX SOLIDS: < 6% Spud the well with a mud consisting of prehydrated bentonite, extender, and caustic soda flocculated into an Inlet water system. String the prehydrated bentonite slurry into the Inlet water system allowing the flocculation to provide the viscosity required for good hole cleaning. If necessary, additional flocculation can be provided by using lime or cement. Both shallow gas and lost circulation may be a problem in this interval. LCM and weight material will be on board for use if needed. In the event of massive lost circulation, the deep well sea Water pumps are capable of pumping water directly into the bell nipple. Controlled drilling will be practiced if required. Due to fast penetration rates and the large diameter hole, the drilled solids content can increase rapidly. Run all solids control equipment to reduce mud dilution requirements. Some controlled drilling may be required. P EEEIV£D MAY 1 9 1995 Aiaska Oil & Gas Coils. Commissior~ Anchorage INTERVAL: HOLE SIZE: CASING SIZE: MUD TYPE: 2500' RKB to 9,750' RKB 12-1/4" 9-5/8" Flocculated Bentonite/Inlet Water System MUD PARAMETERS WEIGHT: 9.0 - 12 ppg VISCOSITY: 50 - 80 sec./qt PV: 15 - 20 YP: 15 - 20 pH: 9.0 - 10.0 FILTRATE: 2 0 SOLIDS: < 8% Drill the 13-3/8" casing shoe and rat hole with spud mud from the preceding interval, routing returns for disposal. Drill to 8000' MD for logs. Log the well and continue on to the 9-5/8" casing point, maintaining mud system properties as in the previous section of hole. Maintain adequate viscosity for effective hole cleaning using the flocculated bentonite. Control any excessive rheology which may develop with Desco-CF on an as needed basis. PAC polymers may be used toward the bottom of the interval for improved well bore stabilization. The reduction in water loss from the PAC treatment will also improve conditions for logging and reduce the possibility of differential sticking. It is possible that some of the sand intervals that may be drilled will still have virgin pressures. This is more of a concern in the Beluga intervals below 6500' TVD. Close attention to the PVT system must be maintained at all times. Coals are again of concern, especially near TD of the interval. Increases in mud weight have been used to control sloughing coals. Increases in the mud weight are of concern given the potential for lost circulation in the depleted intervals. R'ECEIVED UAY 1 9 ]993 & Gas Cons. C0rnrnissi0n Anchorage INTERVAL: HOLE SIZE: CASING SIZE: MUD TYPE: 9,500' RKB to 15,050' RKB (TD) 8-1/2" i! Weighted 3 - 5% KCI Polymer Mud MUD PARAMETERS WEIGHT: 13.5 - 15.0 ppg VISCOSITY: 40 - 50 sec./qt PV: 15 - 25 YP: 10 - 20 pH: 8.5 - 9.5 FILTRATE: 4 - 6 cc/30 min. SOLIDS: 1 4-1 8% KCI: 3 - 5% Drill the 9-5/8" casing shoe and rat hole, routing returns for disposal. Displace with the KCI mud prior to drilling ahead in the 8-1/2" hole. Use a high viscosity fresh water/Barazan pill to separate the old mud from the new. Drill to TD, maintaining mud system properties as listed above and adjusting to those dictated by wellbore conditions. Sodium Bromide, at a concentration of .05 ppb, will be used as the tracer material in this hole section. RE(EIVED MAY Alaska 0ii & Gas Cons. C0mrnissi0~ Anchorage DRILLING FLUID SYSTEM DESCRIPTION MUD STORAGE CAPACITIES PER 20 AAC 25.005 (C) (6) · Ddll Water 13,060 bbls · Bulk Mud 5,600 cu. ft. · Surge Tanks 100 cu. ft. · Liquid Mud (Active System) 1925 bbls · Sack Storage (Approximate) 1,265 sq. ft. MUD FACILITIES AND EQUIPMENT · Shale Shakers: (4) Derrick FIo-Line Cleaners. · Desander: Brandt desander unit charged by 8X6R centrifugal pump driven by 100-hp · explosion-proof motor. · Mud Cleaner: Brandt dual cleaner including two (2) 3-hp 1,800 rpm explosion-proof motors charged by Mission 8X6R centrifugal pump driven by 100-hp electric motor. · Degasser: Wellco model 6200. · Centrifuge: Baroid 24" x 38" High G variable speed decanting centrifuge. · Mud Agitators: 1. One (1) 5-hp explosion-proof electric mud mixer mounted on slugging pit. 2. Four (4) 25-hp explosion-proof electric mud mixers on main mud tanks. 3. Four (4) 2-hp explosion-proof electric mud mixers on sand trap tanks. · Mud-Gas Separator: Global Marine design. · Mud Testing Facilities: Basic kit for viscosity, filtration, weight and titration. · Mud Mixing Pumps: Two (2) Mission 8X6R centrifugal pumps driven by a 100-hp electric motor. · Pit level indicator on active tanks with totalizer at drilling position. · Manifolding to cement surge tank to permit mixing of barite plug at cementing unit. · Gas Detection System: 1. Control Instruments fixed combustible five-point monitor gas detection system with sensors strategically located on the rig. 2. Seigar fixed H2S five-point monitor gas detection system with sensors strategically located on the rig as per state regulations. RECEIVED 1 9 199, Aiaska 0il & Gas Cons. Commission Anchorage g ES/-', NIl E Fi: 13 E.,.:, f L -[ E R TAN I< T A N K 'T A NK ND, :-_¢ NB, 4 NB, 5 I)ERRICK FLI]-LINE I~ ! - _.LE&NER BERRICK FI_D-LINE L. LEAI',IEF,. NFl, :13 ND,4 DERRICK: FLB---LINE CLEANER NO. ~ DERRICK FLB-L. INE ii:LEANER NB, 1 Cementing Program North Foreland #2 per 20 AAC 25.030 13-3/8" Surface Casino Casing Size: 13-3/8" Hole Size: 17-1/2" Depth: 2,500' RKB Top of Cement: Surface Excess Calculated: 200% BHT (Static): 80°F BHT (Circ): 70°F Slurry Components and Properties: Preflush: 20 bbls seawater, with volume and weight adjusted based on hydrostatic considerations Lead: 2375 sacks Class G cement + 1.0% D-79 (chemical extender) + 2.0% S-1 (Calcium Chloride) Slurry Volume 4960 cuft Slurry Weight 12.5 ppg Slurry Yield 2.09 cu. ft./sk Mix water 11.89 gps Thickening time 4+ hours Tail: 500 sacks Class G cement + 0.05 gps D-47 (antifoam) + 2.0 % S-1 (Calcium Chloride) Slurry Volume 575 cuff Slurry Weight 15.8 ppg Slurry Yield 1.15 cu. ff./sk Mix water 4.97 gps Thickening Time 3.5 - 4.0 hours RECEIVED MAY 1 9 1993 AJaska Oil & Gas Cons. Commission Anchorage 9-5/8" Intermediate Casincj Casing Size: 9-5/8" Hole Size: 12-1/4" Depth: 9,750' RKB Top of Cement: 5,850' (500' above Beluga formation) Excess Calculated: 50% BHT (Static): 135°F BHT (Circ): 110°F Slurry Components and Properties: Preflush' 20 bbls seawater, with volume and weight adjusted based on hydrostatic considerations Lead: 625 sacks Class G cement + 1.0% D-79 (chemical extender) + 1.5% D-112 (FLA) + 0.05% D-47 (antifoam) + retarder or accelerator as required. Slurry Volume 1310 cuft Slurry Weight 12.5 ppg Slurry Yield 2.10 cu. ft./sk Mix Water 11.85 gps Thickening time 4.0+ hours Tail: 500 sacks Class G cement + 1.0% D-156 (Fl_A) + 0.05 gps D-47 (antifoam) + 1.0% D-65 (dispersant) + D-801 (retarder) as required. Slurry Volume 575 cuff Slurry Weight 15.8 ppg Slurry Yield 1.15 cu. ft./sk Mix Water 4.97 gps Thickening Time 3.5 - 4.0 hours RECEIVED Alaska Oil & Gas Cons. Cornmission Anchorage 7" Production Casing Casing Size: Hole Size: Depth: Top of Cement: Excess Calculated: BHT (Static): BHT (Circ): ,1 8-1/2" 15,050' 9,500' RKB (minimum 250' above 9-5/8" shoe) 50% 220°F 210°F Slurry Components and Properties: Preflushes: 30 bbls ARCO Spacer-weighted as appropriate Slurry: 815 sacks Class G cement + 35% D-66 (silica) + 1 gps D-600 (latex) + 0.1 gps D- 135 (latex stabilizer) + 1.0% D-65 (dispersant) + 0.05 gps D-47 (antifoam) + D- 801 as required Slurry Volume 1055 cuft Slurry Weight 17.0 ppg Slurry Yield 1.30 cu. ft./sk Mix Water 4.5 gps Thickening Time 3.5 - 4.0 hours Fluid Loss 100 cc/30 min. Free Water 0 cc REEEIVF. D MAY 3 9 3993 Alaska 0il & Gas Cons. Commission Anchorage PRESSURE INFORMATION ARCO-Phillips' North Foreland #2 per 20 AAC 25.035 (d) (2) The following presents data used for calculation of anticipated surface pressures (ASP) during drilling for the Sunfish well: Casing Setting Depth Rationale 3O" 100' BML 13-3/8" 2,500' RKB, 2,300' BML 9- 5/8" 9,750' RKB, 9,550' BML ii 15,050' RKB, 14,850' BML Structural casing. Depth as required by 20 AAC 25.030(b)(1). This string of casing will top set the Sterling formation. It will provide a good anchor for the BOPE to ensure sufficient fracture gradient for well control while drilling the next interval. Intermediate casing to isolate potential shallow gas zone (Beluga Fm) and Lower Tyonek. Production casing/liner to isolate primary objective Sunfish sand interval and the secondary objective North Foreland sand interval for prospective testing. Casing Size (in.) 30 13-3/8 9-5/8 Casing Pore Setting Fracture Pressure Depth Gradient Gradient (ft. RKB) (lbs/gal) (lbs/gal) Anticipated Pore ASP Max MW Pressure Drilling (lbs/gal) (psi) (psi) 300 8.8 8.7 10.0 135 104 2,500 14.8 9.1 12.0 1 183 806 9,750 17.0 11.0 15.0 5577 2636 RECEIVED MAY 1 9 199;~ ^laska Oil & Gas Cons. Commission Anchorage Casing Performance Properties Internal Collapse Tensile Strength Size Weight Grade Conn. Yield Resistance Joint Body (in) (Ib/ft) (psi) (psi) (1000 lbs) 30 1 -1/2" B D-60 3150 3000 2600 wall I 3-3/8 72 N-80 BTC 5380 2670 1693 1661 9-5/8 53.5 L-80 BTC 7930 6620 1286 1244 7 . 35 L-80 BTC 8460 10180 833 814 Casing Design Safety Factors 13-3/8" 72 N-80 BTC 6.67 8.50 11.1 10.9 9-5/8" 53.5 L-80 BTC 3.09 4.19 3.10 3.00 7" 35 L-80 BTC 3.29 1.27' 2.10 2.05 * Calculation using DST condition. Procedure for Calculating Anticipated Surface Pressure (ASP) 1. Drilling below Structural and Conductor Casing ASP is determined on the basis of breakdown of the formation at the casing seat with a gas gradient to the surface as follows: ASP = [(FG x 0.052) - 0.11]D where: ASP = Anticipated Surface Pressure in psi FG = Fracture Gradient at the casing seat in lb/gal 0.052 = Conversion from lb/gal to psi/ft 0.11 = Gas gradient in psi/ft D = True vertical depth of casing seat in ft RKB 2. Drilling Below Surface Casing ASP is determined on the basis of breakdown of the formation at the casing seat with accompanying complete loss of returns and the hole filled with seawater: ASP = (FG - 8.60) x 0.052 x D where: 8.60 = density of seawater in lb/gal RECEIVED MAY 1 9 199,t Alaska 0il & Gas Cons. C0mm[ss~On Anchorage 3. Drilling Below Intermediate Casing / Drilling Liner ASP is determined on the basis of breakdown of the formation at the casing seat, an accompanying mud level drop of 1/2 of the shoe depth and the remainder of the wellbore filled with seawater: ASP = BHP - MUD COLUMN WEIGHT - SEAWATER COLUMN WEIGHT ASP = FG (.052) D -[MW (.052)] .5 D -[8.6 (.052)] .5 D where' ASP = Anticipated Surface Pressure in psi FG = Fracture Gradient at the casing seat in lb/gal 0.052 = Conversion from lb/gal to psi/ft 8.60 = density of seawater in lb/gal MW = drilling mud weight lb/gal D = True vertical depth of casing seat in ft RKB ASP Calculations 1. Drilling below structural casing (30") ASP= [(FG x 0.052) - 0.11]D = [(8.8 x 0.052) - 0.11] 300 = 104 psi 2. Drilling below surface casing (13-3/8") ASP = (FG - 8.60) x 0.052 x D = (14.8 - 8.60) x 0.052 x 2500 = 806 psi 3. Drilling below Intermediate casing (9-5/8") ASP : FG (.052) D -[MW (.052)] .5 D -[8.6 (.052)] .5 D = 17.0(.052) 9750 -[15.0 (.052)(4875)] -[8.6 (.052)(4875)] = 2636 psi RECEIVED MAY I 9 199) ~,Jaska Oil & Gas Cons. Anchorage Memorandum State of Alaska Oil and Gas Conservation Commission To: Commission ~'tt6 ~/q June 8, 1993 ? Variance RequesU- ARCO No~ Foreland St. ~2 Fm; Subj: ARCO's request for exception to 20 ACC 25.030 ~) 2 is predicated on experience while drilling Sunfish 1, Sturgeon 1, and North Foreland St. No. 1. Drilling information fi.om the above referenced wells confirmed shallow seismic surveys which also showed no indications of shallow gas prior to drilling. Arco and their contractors provided the results of shallow seismic surveys around North Foreland St. No. 2 on 6/8/93 at the AOGCC office. The results of the surveys showed no indications of shallow gas above 3500'. A previous review of wells nearby showed no abnormal drilling conditions nor indications of shallow gas in the surface holes. Based on lack of indications of shallow gas hazards, the staff recommends approval of the variance to casing setting requirements of 20 AAC 25.030 b(2), and support setting 13 3/8" to 2500' MD (2300' BML) in NF St. No. 2. The variance to H2S requirements, 20 AAC 25.065, is reasonable in that there has been no evidence of H2S in the Sunfish and North Foreland St. wells. ARCO indicated that there will be monitoring equipment on board and in use to detect H2S and measures would be enacted if it is detected while drilling. ARCO Alaska, Inc. r~ ~ Post Office Box l b,,~60 Anchorage Alaska 99510-0360 Telephone 907 276 1215 May 18, 1993 D. W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Application for Permit to Drill ARCO-Phillips North Foreland g2 (NF ~2) Dear Commissioner Johnston: ARCO Alaska, Inc. hereby applies for a Permit to Drill (APD) an offshore exploratory / delineation well, the ARCO-Phillips North Foreland g2 (NFg2), in State waters of the Cook Inlet. ARCO will act as operator for itself and Phillips Petroleum Company in evaluating acreage previously leased in State of Alaska Lease Sales. The proposed well location is approximately 6 miles southwest of the Phillips North Cook Inlet Platform in about 46 meters of water. ARCO proposes using the 'Glomar Adriatic VIII' jack-up drilling rig to drill this well beginning as soon as all .permits are acquired in 1993. As part of this application for permit to drill, ARCO Alaska, Inc. formally requests a variance to the setting depth of casing shown in 20 AAC 25.030(b)(2). It is requested that the maximum 1000' depth BML be extended to 2300' BML (2500' RKB) as noted on the permit. This request is discussed further in the attachments to the APD. We further request exemption from the requirements in 20 AAC 25.065 relating to hydrogen sulfide. H2S was not encountered in either the Sunfish gl or North Foreland gl wells and is not expected in the NF g2. At NF g2 it is ARCO's intent to monitor for the Presence of H2S while drilling the entire well. If H2S is detected, the Commission will be notified as required and contingency equipment will be installed immediately. We further request exemption from the requirements in 20 AAC 25.035 relating to weekly BOPE tests being taken to the rated working pressure of the equipment. The initial test of the BOPE's will be to the rated pressure but we request that the weekly tests be conducted to 70% of the last casing string run. This procedure will save unnecessary fatigue on the equipment. As required by 20 ACC 25.005 (c) (10), ARCO Alaska, Inc. requests permission to utilize the 13-3/8" X 9-5/8" casing annulus for pumping of drilling muds incidental to the drilling of this well. The end of well reports, Completion Report 20 AAC 25.070 and Geologic Data and Logs 20 AAC 25.071 will be provided by James Trantham 265-6434 and Mike Navolio 365-6191 respectively. Weekly operational updates James Trantham. ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company MAY 1 9 199 Alaska Oil & Gas Cons. Oommiss%on Anchorage Please note that we are currently evaluating a shallow hazards survey and we will forward this information as soon as we receive it. In accordance with usual practices, the AOGCC is requested to keep this application and attachments confidential. If you have questions please contact myself at 265- 6434 or Mike Winfree at 263-4603. Thank you for your attention. Si cerely, --r'--. J"-~ames A. Trantham Drilling Engineer Attachments CC.' North Forelands #2 Well File J. R. Winegamer ATO-1934 M. E. Navolio ANO-748 RECEIVED MAY 1 9 t993 · Alaska Oil & Gas Cons. (.;ommissJon Anchorage 1£: ~OPM ~I EXPLOR~DRILLIM~ BOP CO M P_C)_NENTS per 20 AAC 25.035 (d) (2) 1. t3.6/$", 5000 poi WP, Hydril ;~nnular provcnter with oornpanion flange to befl nipple. 2. Double 13.5/8", 10,000 psi WP type "U" Cameron blowout preventer fitted with 5" pipe r;~ms top and blind rams bottom. 3. Double ] 3-,5/8', 10,000 psi WP type "U" Cameron blowout preventer fitted with 5"l~ipe rams top and bottom. 4. 13-5/8", 10,000 psi X 13-5/8', 10,000 psi Drilling Spool. Ch~)ke,, Valves; ,~. 3-1/16", 10,000 psi WP hydr~tulic valve 6. 3-1/16", lO,O00-psi WP manual valve Kifl Valves: 7. 3-I/16", 10,000 psi wP manual valve 8. 3-1/16", 10,000 psi WP hydraulic valve Glomar Adriatic VIII RECEIVED JUN 08 '93 1~: llPM RAI EXPLO~/D~ILLIMG BOP SCHEMATIC per 20 ACC 25.035 (a) (1) F: i3-5/8", 10,000 PSI, RRRRA See listing of Incilvi;Jual components on following page. Glomar Adriatic ViII JUN 0~ ~3 F1RI m.. ;x;I--'LU~/U~ 1 LL.I. rt~ DiVERTER SCHEMATIC per 20 ACC 25.035 (a) (1) Flowl!,ne Ilil I . . II MSP-IO00, 30" Annular Preventer ~ ~, .. ,,,~: , ...,, ~ / 12'", 2000 psi . ,, a 12", 2000 PSi Hydraulic Valve ! J Hy~ic Valve *~ 30", 1000 psi Spool 30" X 1-1/2" Drive Pipe RECEIVED .... ,: ,:,~ Alaska Oil & 68.s L;or~s. Commission Ancho~'age Glomar Adriatic VIii ARCO Alaska, Inc. ~ Post Office Box lbu360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 May. 28, 1993 Mr. Mike Minder Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Casing Variance Request ARCO~Phillips North Foreland #2 (NF#2) Casing Design Assumptions Dear Mr. Minder: Please find attached more information you requested regarding the casing setting depth variance and the casing design assumptions in the APD of the subject well. If you need additional information, please contact me at 265-6434 or Steve Robinson at 265-1176. Thank you in advance for your attention. Sincerely, ,James lrantham Drilling Engineer Attachment (2) XC: S. W. Robinson E. G. Mazzolini North Foreland #2 Well File RECEIVED J UN - 1 199~ Alaska Oil & Gas Cons. C0mrnlssio~ Anchorage ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company CASING DEPTH SETTING JUN - 7 993 Alaska Oil & Gas Cons. C0rr]missio~ VARIANCE REQUEST Anchorage ARCO Alaska, Inc. (AAI) requests a variance to the required setting depth of the conductor casing as specified in 20 AAC 25.030(b)(2) for the ARCO/Phillips North Forelands #2 (NF#2) well. The proposed conductor string in NF#2 is 13-3/8", 72#, N-80. The proposed setting depth is approximately 2300' below mud line. AAI is requesting this variance based on the operating experiences gained at the Sunfish #1, North Foreland State #1, and Sturgeon #1 and the specific drilling information gained at Sunfish #1 and North Foreland State #1. By approving the change in conductor setting depth, the hole/casing design planned for NF#2 will be optimized and allow the operating experiences gained in the most recently drilled wells to be employed to significantly reduce the anticipated operating time without incurring undo risk. AAI has conducted shallow seismic surveys in the immediate areas of the Sunfish #1, North Foreland State #1 and the intended locations of the NF#2 well. All reports have been previously submitted to the Commission. When presented to the Commission, the report findings were discussed. In the case of the first planned well, Sunfish #1, it was interpreted that according to seismic information no significant shallow hazard existed at the proposed location. Drilling confirmed the analysis. When the North Foreland information was presented, the same conclusion was reached and verified when drilled in the 1992 drilling season. In the intervals above 3500' RKB in both the Sunfish and North Foreland wells, no drilling anomalies were encountered. The mud weights used were at most 9.0 ppg and the actual mud weight was dictated by the drilled solids content of the mud rather than any added barite. At no time during the drilling of these intervals was there any indication of or attempt by the well to flow. When the initial hole intervals (-300'- 1200' RKB) were drilled on Sunfish and North Foreland (316- 2500' on North Foreland), a 12-1/4" pilot was employed. This approach results in exposing a minimal wellbore area and allows a quicker reaction time to any potential flow. Since the hole size difference between 17-1/2" and 12-1/4" is not as significant as in the earlier wells, it is planned to drill this interval on NF#2 with a 17-1/2" bit. No hole opening will be required. Mud flow into and out of the well is monitored with two independent PVT systems, the rig's own and the mud logger's. In the event of lost circulation a fillup line connected to the rig's sea water pumps has been installed to allow the hole to be flooded with sea water. With regard to diverter and BOP equipment, reference is made to the diagrams included elsewhere in this application. It is planned that a 30" diverter, as employed on the past wells, will be used while drilling below the 30" drive pipe. The diverter lines are 12" and extend in straight runs from the spool to beyond the cantilever deck beams. A 13-3/8" BOP stack will be in use while drilling below the 13-3/8" casing (2300 BML). This is in contrast to the use of the 30" diverter on both the 30" structural and the 20" conductor casings in the past wells. If a conductor string is required at approximately 1200' (1000' below mud line), insufficient formation integrity at the shoe would preclude shutting in a BOP stack since poor rock strength at this depth would result in an underground blowout which would broach the seafloor. Therefore, setting the conductor in rock with sufficient rock strength (2300' BML) results in a more reliable well control situation sooner, than if a diverter system is used until the next casing point, probably 3500' as in Sunfish #1. In support of this request, several wells in the Cook Inlet area have been identified where the conductor casing string (String 2) has been set deeper than 1000' below mud line or ground level. The wells and the RKB-TVD casing depths are: Well String 1 String 2 Stdng 3 ARCO Fire Island #1 30"@ 328' 20"@ 1685' 13-3/8" @ 7603' Stuart W. McArthur RU #1 30"@ 127' 20"@ 2040' unknown Phillips NCIU A-12 30"@ 381' 20" @ 1990' 13-3/8" @ 6950' ARCO/Phillips North Foreland #1 30" @ 316' 20" @ 2489' 13-5/8" @ 8498' ARCO Funny River #1 30"@ 60' 20" @ 2971' 13-3/8" @ 8312' ARCO Beluga RU 214-26 20'@ 95' 13-3/8" @ 2985' 9-5/8" @ 6442' CASING PERFORMANCE SAFETY FACTOR CALCULATIONS SAMPLE CALCULATIONS FOR: I. 9-5/8", 53.5#, L-80, BTC - INTERMEDIATE / PROTECTIVE CASING A. INTERNAL YIELD / BURST Csg Burst Rating = 7930 psi Anticipated Surface Pressure while drilling ahead = 2636 psi (See Calcs for ASP) SF b = 7930/2636 = 3.01 B. COLLAPSE RESISTANCE Csg Collapse rating Evacuation depth = 6620 psi = Csg Depth (1 - pore press grad / expected max mw) = 9750 (1 - 11/15) = 2600 feet P external @2600' = 2600 * 0.052 * 11.7 (mw used when cmtg the csg) = 1580 psi SF c = 6620 / 1580 = 4.19 In case of complete evacuation (very unlikely), P external at shoe = 0.052 * 11.7 * 9750 = 5932 psi S F c = 6620 / 5932 = 1.12 C. TENSILE STRENGTH Buoyed Csg Weight = 53.5 * 9750 * (1 - 11.7/65.44) = 428,364 lbs S F Tj = 1,286,000 / 428,364 = 3.00 S F Tb = 1,244,000 / 428,364 = 2.90 II. 7", 35#, L-80, BTC - PRODUCTION CASING A. INTERNAL YIELD / BURST Csg Burst Rating = 8460 psi S F b = 8460 / 2636 = 3.21 If well is deepened and drilled below 7" shoe: ASP = 18 * 0.052 * 15050 - (15 + 8.6) * 0.052 * 7525 = 4852 psi SF b = 8460 / 4852 = 1.27 RECEIVED J U N - 1 199;) Alaska Oil & Gas Cons. (;ommissio~; Anchorage B. COLLAPSE RESISTANCE Csg Collapse Rating = 10180 psi Sunfish DST (base on NF #1 DST data) Estimated Sunfish sand depth = 13850' P internal @perf = 2500 psi P external = 0.052 * 13850 * 14.6 (mw used when cmtg the csg) = 10,516 psi P collapse = 10,516- 2500 = 8,016 psi SFc = 10180/8016 = 1.27 C. TENSILE STRENGTH Buoyed weight = 35 * 15050 * (1 - 14.6/65.44) = 409,229 lbs SF Tj = 833,000 / 409,229 = 2.04 SF Tb = 814,000 / 409,229 = 1.99 RECEIVED JUN - 1 199; Alaska 0ii & Gas Cons. Commissio,' Anchorage PRESSURE INFORMATION ARCO-Phillips' North Foreland #2 per 20 AAC 25.035 (d) (2) The following presents data used for calculation of anticipated surface pressures (ASP) during drilling for the Sunfish well: Casing Setting Depth Rationale 30" 100' BML 13-3/8" 2,500' RKB, 2,300' BML 9- 5/8" 9,750' RKB, 9,550' BML ii 15,050' RKB, 14,850' BML Structural casing. Depth as required by 20 AAC 25.030(b)(1). This string of casing will top set the Sterling formation. It will provide a good anchor for the BOPE to ensure sufficient fracture gradient for well control while drilling the next interval. Intermediate casing to isolate potential shallow gas zone (Beluga Fm) and Lower Tyonek. Production casing/liner to isolate primary objective Sunfish sand interval and the secondary objective North Foreland sand interval for prospective testing. Casing Pore Casing Setting Fracture Pressure Size Depth Gradient Gradient (in.) (ft. RKB) (lbs/gal) (lbs/gal) 30 300 8.8 8.7 I 3-3/8 2,500 14.8 9.1 9-5/8 9,750 17.0 11.0 Anticipated Pore ASP Max MW Pressure Drilling (lbs/gal) (psi) (psi) 10.0 135 104 12.0 1183 806 15.0 5577 2636 RECEIVED d UN - 1 1993 Alaska Oil & Gas Cons. OommissJor' Anchorage Casing Performance Properties Internal Collapse Tensile Strength Size Weight Grade Conn. Yield Resistance Joint Body (in) (Ib/ft) (psi) (psi) (1000 lb,t,) 30 1 - 1/2" B D-60 31 50 3000 2600 wall I 3-3/8 72 N-80 BTC 5380 2670 1693 1661 9-5/8 53.5 L-80 BTC 7930 6620 1286 1244 7 35 L-80 BTC 8460 10180 833 814 Casing Design Safety Factors 13-3/8" 72 N-80 BTC 6.67 8.50 11.1 10.9 9-5/8" 53.5 L-80 BTC 3.09 4.19 3.10 3.00 7" 35 L-80 BTC 3.29 1.27' 2.10 2.05 * Calculation using DST condition, Procedure for Calculating Anticipated Surface Pressure (ASP) 1. Drilling below Structural and Conductor Casing ASP is determined on the basis of breakdown of the formation at the casing seat with a gas gradient to the surface as follows: ASP = [(FG x 0.052) - 0.11]D where: ASP = Anticipated Surface Pressure in psi FG = Fracture Gradient at the casing seat in lb/gal 0.052 = Conversion from lb/gal to psi/ft 0.11 = Gas gradient in psi/ft D = True vertical depth of casing seat in ft RKB 2. Drilling Below Surface Casing ASP is determined on the basis of breakdown of the formation at the casing seat with accompanying complete loss of returns and the hole filled with seawater: ASP = (FG - 8.60) x 0.052 x D where: 8.60 = density of seawater in lb/gal RECEIVED d U N - 1 199, Alaska 0il & Gas C0~ls. Anchorage 3. Drilling Below Intermediate Casing / Drilling Liner ASP is determined on the basis of breakdown of the formation at the casing seat, an accompanying mud level drop of 1/2 of the shoe depth and the remainder of the wellbore filled with seawater: ASP = BHP - MUD COLUMN WEIGHT - SEAWATER COLUMN WEIGHT ASP = FG (.052) D -[MW (.052)] .5 D -[8.6 (.052)] .5 D where: ASP = Anticipated Surface Pressure in psi FG = Fracture Gradient at the casing, seat in lb/gal 0.052 = Conversion from lb/gal to psi/ft 8.60 = density of seawater in lb/gal MW = drilling mud weight lb/gal D = True vertical depth of casing seat in ft RKB ASP Calculations 1. Drilling below structural casing (30") ASP= [(FG x 0.052) - 0.11]D = [(8.8 x 0.052) - 0.11] 300 = 104 psi 2. Drilling below surface casing (13-3/8") ASP = (FG - 8.60) x 0.052 x D = (14.8 - 8.60) x 0.052 x 2500 = 806 psi 3. Drilling below Intermediate casing (9-5/8") ASP = FG (.052) D -[MW (.052)] .5 D -[8.6 (.052)] .5 D = 17.0(.052) 9750 -[15.0 (.052)(4875)] [8.6 (.052)(4875)] = 2636 psi RECEIVED JUN - 1998 ~laska Oil & Gas Cons. (~0mrnissi0r~ Anchorage ~tate: Alaska Borough: Well: N. Fodand St. #2 Field: Wildoat St. Perm # 93-78 NFST2CSG.XI.S Date 5121 Engr: M. Minder Casing Interval Interval Size Bottom Top 1A 1:3.375 2500 47 ?.A 9.625 9750 47 3A 7 15050 47 4A 0 0 0 5A 0 0 0 6A 0 0 0 7A 0 0 0 8A 0 0 0 9A 0 0 0 10A 0 0 0 Length 2453 9703 15003 0 0 0 0 0 0 0 Description Description Description Tension Lbs Grade Thread Lbs 72 N-80 BTC 0 53.5 L-8~) BTC 0 :35 L-80 BTC 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Mud Hydraulic Collapse Weight Gradient Gradient ppg psi/It psi/ft 1B 9.7 0.504 0.404 2B 9.8 0.510 0.410 3B 9.0 0.468 0.:368 4B 0.0 0.000 -0.100 5B 0.0 0.000 -0.100 6B 0.0 0.000 -0.100 7B 0.0 0.000 -0.100 8B 0.0 0.000 -0.100 9B 0.0 0.000 -O.100 10B 0.0 0.000 -0.100 Maximum Minimum Pressure Yield psi psi BDF 26:36 3450 1.3 2636 6870 2.8 2636 7224 2.7 0 0 #DIV/0! 0 0 #DIV/O! 0 0 #DIV/O! 0 0 #DIV/0! 0 0 #DN/OI 0 0 #DN/'O! 0 0 #DN/0! Tension Strength K/Lbs K/Lbs 1C 176.616 1069 2C 519.1105 1086 3C 525.105 604 4C 0.014 5C 0 6C 0 7C 0 8C 0 9C 0 10C 0 TDF 6.05 2.09 1.15 0.00 #DN/O! #DN/O! #DN/O! #DlV/O! #DIV/O! #ON/O! Collapse Collapse Pr-Bot-Psi Resist. CDF 1011 1950 1.929 3994 4750 1.189 5538 5410 0.977 0 0 #DIV/O! 0 0 #DIV/O! 0 0 #DN/O! 0 0 #DN/O! 0 0 #DN/0! 0 0 #DIV/0! 0 0 #DIV/O! NFS112CNITXLS State: .41~ Engineer. "~ell: N. Fodand St. #2Work Sheet: Field: Wildoat Date: State Permit 1~ 93-78 Cas'rng T ~,e Casing Size-Inches Casing Length - Feet Hole Diameter -Inches C. emm'~ - Sacks 111 Cement- Y'~I 111 Cement- CulYc fl ~1 C~- C~ fl ~1 C~- S~s ~2 Ce~- ~ ~2 C~-~ ft ~2 C~- ~ fl fl2 ~~- Sa~s ~3 C~- Y~ ~3 C~- ~ fl fl3 C~- ~ ft fl3 ~-~fltV~ Cem~t - Fill Faotor C. axkmtm Surface 0.000 13.375 O.000 2,453.0~ 0.000 17.500 0.000 0.000 0.000 0.000 0.000 0.000 O.000 4,980.OO0 0.000 O.00O O.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 5,535.000 tM)iV/0! 3.248 Linel 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 ltBIV/0! C. es~ T~e Cask~ Sk, e -I~ Ca~ing Depth - Feet Hole Diameter -Incl~ ~- Sac~ 111 Cemer~ - Cubic fl 111 Cement- Cubic it 111 Cerr..e~ - Sacks ~2 C~- Y~ ~2 ~- S~s ~3 C~- ~ ~3 C~- ~ fl ~3 C~-~fl/VOl Cemmi- Iniaval fl Top of Cement- Feet Inie, neE~e fll InimmeE~e fl2 Roductbn 0.000 7.OOO 9.625 0.000 15,050.000 9,750.000 0.000 g500 1Z250 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 1,055.00 1,310.00 O.00 O.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 575.00 0.00 0.00 0.00 0.00 0.00 0.00 O.00 0.00 0.00 0.00 0.00 0.00 0.00 1,055.00 1,885.00 11DIW0! 8,31g.75 6,018.87 ltl)iV/0! 6,730.2 3,731.1 Measured Depth PHILLIPS PETROLEUM HOUSTON, TEXAS 77251-1967 BOX 1967 NORTH AMERICA EXPLORATION AND PRODUCTION COMPANY April 28, 1993 BELLAIRE, TEXAS 6330 WEST LOOP SOUTH PHILLIPS BUILDING Notice of Request for Exception to 20 AAC 25.055 Nm'th Foreland No. 2 Well Cook Inlet, Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Gentlemen: Reference is made to that certain Notice of Request for Exception dated April 23, 1993, provided by ARCO Alaska, Inc., and covering the above captioned well. Please be advised that Phillips Petroleum Company has no objections to the Alaska Oil & Gas Conservation Commission granting this request. Should you have any questions, please contact the undersigned at (713) 669-3729. Very truly yours, PHILLIPS PETROLEUM COMPANY Brett A. Butterfield General Landman CC: BAB\Ijo 0493.15 James R. Winegamer ARCO Alaska, Inc. RECEIVED M AY - 3 Alaska 0il & Gas Cons. commission Anchorage ** CHECK LIST FOR NEW WELL PERMITS ::* ! TEM APPROVE DATE (2) Loc 'f?F , [2 thru (3) Admin [9 .thru l~J] ' ' ElO & 13] [14 thru 22] [23 thru 28] [ 29 thru- (7) Contact [32] (8) Addl ,~,~ ~-~-~'~ geo 1 ogy' eng i nee r i ag' rev 12/92 jo/6.011 . 2. 3. 4. 5. . 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. !.9. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. 33. Company ARQ. O YES NO Is permit fee attached ............................................... Is well to be located in a defined pool .............................. Is well located proper distance from property line ................... Is well located'proper distance from other wells ..................... Is sufficient c~dedicated acreage available in this pool ............. Is well to be deviated & is wellbore plat included ................... Is operator the only affected party .................................. Can permit be approved before 15-day wait ............................ Does operator have a bond in force ................................... Is a conservation order needed ........................................ Is administrative approval needed .................................... Is lease ncrnber appropriate .......................................... Does well have a unique name & n~ber ................................ Is conductor string provided ..................................... ~... Wi 11 surface casing protect al 1 zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on c~ndu:%:~-S surface ............ Will cement tie in surface & intermediate or production strings ...... W i 11 cement cover al 1 known product i ve hor i zons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating-- test to~d~oo~psig ..... Does choke manifold comply w/APl RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORT & STRATIGRAPHIC WELLS' Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone ncmber of contact to supply weekly progress data ...... Add i t i ona 1 requ i rements ............................................. INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE REMARKS Additional remarks' O ..--! UM MERIDIAH' SM X Dev ,~ Inj TYPE: i 11 Rev