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Home My WebLink About187-088Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. /__ ~ ¢- ~ ~ ~' Well History File Identifier Organization (done) r~ Two-Sided RESCAN DIGITAL DATA /~ Color items: [] Diskettes, No. [] Grayscale items: [] Other, No/Type [] Poor Quality Originals: [] Other: TOTAL PAGES: .r~'~ / NOTES: ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) Logs of various kinds Other Isl Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl Scanned (done) PAGES: ~I (at the time of scanning) SCANNED BY2 ~BREN VINCENT SHERYL MARIA LOWELL DATE: RESCANNEDBY: BEVERLY BR~ SHERYL MARIA LOWELL General Notes or Comments about this file: PAGES' Quality Checked (done) Rev1 NOTScanned.wpd Memorandum State of Alaska Re' Oil and Gas Conservation Commission To: Well File: ~0"'~'- ~ C)(~3~(~ DATE Cancelled or Expired Permit Action EXAMPLE: Point McIntyre P2-36AXX API# 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 ddil. 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 reddiis and or multilaterals in a well. In order to prevent confusing a cancelled or expired permit with an active well or multilateral these case sensitive well identifiers will be changed for expired and cancelled applications for permits to ddll. The APl number for this cancelled or expired permit is modified so the eleven and twelfth digits is 95. The well name for a cancelled or expired permit is modified with an appended xx. These procedures are an addendum to the APl numbering methods described in AOGCC staff memorandum "Multi-lateral (weilbore segment) Ddlling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. e McMains - ~ Statistical Technician ALASKA OIL AND GAS CONSERVATION COMMISSION May 5,1993 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 J. Michael Robbins 540 L St Ste 205 Anchorage, AK 99501 Dear Mr. Robbins: We have received your April 23 letter requesting access to all information relating to wells permitted by Amerada Hess Corporation; and your May 3 telecopy of the protective order issued by the District Court in Case No. N90-004 Civ. Pursuant to Title 31, Section 31.05.035 of the Alaska Statutes, the Commissioner of Natural Resources has found that the well file on Colville Delta 25-13-6 No. 1 contains significant information relating to valuation of unleased land in the same vicinity. This well has been classified as confidential indefinitely, and will remain so until released by the Commissioner. Currently, we are seeking advice from the Depadment of Law as to the appropriate response to your request in view of the above referenced protective order. Due to workload constraints and the need to consult with legal counsel, we are unable to respond fully to your request within ten working days per 6 AAC 95.070. We anticipate furnishing the requested records, or issuing a determination that they are not disclosable, by May 24, 1993. This extension is not interposed for the purpose of delay. The following is a complete list of permits issued to Amerada Hess. PERMIT APl # WELL NAME WELL WELL CLASS STATUS 85-0085-0 029-21341-00 Northstar 1 expl susp* 85-0278-0 103-20054-00 Colville Delta 25-1 expl conf indef 85-0279-0 103-20055-00 Colville Delta 32-1 expl expired 86-0013-0 029-21511-00 Northstar 2 expl p&a* · 87~0088-0 629-21747-00 Northstar 3 expl expired *The two publicly available well files can be reviewed at our office. Please contact Larry Grant at 279-1433 to schedule a time convenient for you. For your records, Mr. Chatterton retired in August, 1990. David W. Johnston is currently chairman of the Commission. Yours very truly, Russell A. Douglass. Commissioner rpc/jo~amerhess RMERRDR HESS CE)RPEIRRTION September 8, 1988 Mr. C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3!92 Re' Northstar Island P. O. BOX 2040 TULSA, OKLAHOMA 74102 9 I 8-599-4200 COfv!M j,//c ............... ~...~ '-' 'k-4 ' r,,.-'-.-- [:: r,,!,,:~ A.:;,:., i. I 1 ....... Dear Chat' In my letter of August 12, 1988, I stated that I would notify you when Amerada Hess Corporation had completed the repairs on Northstar Island. We completed the work on August 25, 1988 and demobilized equipment on August 27, 1988. Repairs consisted of re-anchoring concrete blocks, grooming the northeast/east side of the island, and placing approximately 2,500 four cubic yard bags of gravel. We are hopeful that these repairs will provide island integrity until a determination has been made as to what to do with the prospect. Sincerely, C. R. Richard Manager, Engineering & Technical Services yb xc' Judy Brady - Commissioner of Natural Resources Jim Eason - Director of Natural Resources Jerry Brossia - Regional Manager, Division of Land & Water RECEIVED , EP 1 1988 Alaska 0il & 6as Cons. Commission Anchorage August 31, 1987 Mr. L. A. Dinneen Amerada Hess Corporation 2744 Iliam~na Drive A~chorage, Alaska 99517 Telecopy.- (907) 276-7542 Re: Northstar No. 3 Amerada Hess Corporation Permit No. 87-88 Sur. Loc. 500'FWT~, 600'F1~, Sec. 3, T13N, R13E, UPM. Btmhole Loc. 500:F~tL, 600'Fbi, Sec. 3, T13N, R13E, UPM. Dear Mr. Dinneen: Enclosed is the approved application for permit to drill 'the above referenced well. .The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 .hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. I~Pnere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE CO~{ISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ALASKA /"~"[ la. Type of work Drill Redrill Re-Entry [] Deepen STATE OF ALASKA AND GAS CONSERVATION CC PERMIT TO DRILL 20 AAC 25.005 vllSSlON lb. Type of well. Exploratory [] Stratigraphic Test ¢ Development Oil Service ~ Developement Gas Fq Single Zone ~ Multiple Zone 2. Name of Operator Amerada Hess Corporation 3. Address 1185 Avenue of the Americas New Y0rk, New:YOrk 10036 4. Location of well at surface 11,013 ft. NSL, ~%2~. ,4 ft. EWL, Lease Block BF-47 (ADL 312799) At top of groductive interval" Same (straight hole) At total depth Same (straight hole) 12. Distance to nearest property line No Lease line 3150 feet 13. Distance to nearest well BHL Seal No. 1 5300feet 5. Datum Elevation (DF or KB) RKB 8,5 feet 6. Property Designation ADL 312799 (BF-47) 7. Unit or property Name Northstar Project 8. Well number Northstar No. 3 9. Approximate spud date Oct. 1, 1987 14. Number of acres in propert 4472.37 10. Field and Pool Exploratory Well Northstar. Seal Island Area 11. Type Bond (see 20 AAC 25.025) Statewide Number Seaboard Surety No. 948498 (on file) Amount $200,000 15. Proposed depth (MD and TVD) 11,350 feet 16. To be completed for deviated wells (straight hole) Kickoff depth feet Maximum hole angle 18. Casing program size Hole Casing 26" 20" 7 1/2" 13 3/8" 2 14" 12 1/4" 8 1/2" 9 5/8" 9 5/8- 7 I! Specifications WeightlGrade]Coup'ingl~ngth 133 IK-55 I BTC i 427 ~47.0 IL-8° I BTC i==0o I / BTC 26.0 INT85HS§ ~TC I 950 19. To be completed for Redrill, Re-entry, and Deepen O Present well condition summary Total depth: 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) 0 Maximum surface 3904 psig At total depth (TVD) 5607 measured true vertical Setting Depth Top Bottom MDI tVdI MDI TVD 0 I 01427 I 427 0 I 0! 3000I 3000 o ! o I I ==oo I I O, OOI ,o, oo 10,400 110,400 111,3501 11,350 )erations. feet Plugs (measured) feet psig Quantity of cement (include stage data) t;irc.to, mJ. w/ ~uucu. lt. coldset II ;irc. to 5U~ w/ 4940cu. ft. ~ol~$~t ~' 322 cu, ft, Class "G" w/add it ives 295 cu. ft. Class "G" w/add i t i van Effective depth: measured true vertical feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True Vertical depth measured true vertical 20. Attachments Filing fee ~, Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program Drilling fluid program [~ Time vs depth plot ~ Refraction analysis ~ Seabed report [] 20 AAC 25.050 requirements 21. I hereby certify,~at the foregoing is true and correct to the best of my knowledge La_r r~ nneen .........,,] , S~gned~/~-~'z.~¢~-1.~_~¢~ Title Designated Agent Commission Use Only Permit Number I APl number I Approval date FY ~,~ 50--(~ ~-? ~;~-/?cf~ 08/31/87 Conditions of approval Samples required ~. Yes [] No Mud log required "l~'Ye.s Hydrogen sulfide measures [] Yes [] No Directional survey required [] Yes Required working.~.r..P.~su~~~ E]~/I; ~[] 3M; Oth r:. F//4/? Approved by ~,....~'-, Z k_.,y~ Form 10-401 Rev. 12.1-85 --! / / Date 8/20/87 See cover letter for other requirements [] No g No 5M; [] 10M; [] 15M ....... by order of e~ Commissioner the commission Dar Submit 2O tD I ' : q_ Oe IJe O~ J . J ~ OPEN AMOCO 0CS-0175 '.AMOCO ~,~.C S -0179 NORTHSTAR ~' ~-'"~_.,~ __ __ __ (~).. NORTHSTAR NO,2 AM ERADA HESS BF-46 BEAUFORT SEA AMOCO OCS -0179 I AMERADA HESS 4284? . LOCATION: ~r~ ~" 0 NORTHSTAR NO. 3 70o30'41.8'' ~L A T~"'-~ ,5,3 148°46'2. Z'' LONG '~ '~,. Seal Y: 6,038,273,87 X: 650,630.26 ASPC ZONE 4 ADL 31279~ AMERADA HESS BF-47 Seal#4 S/Till Seal ~ 4 ,,,' ii Orig. Hole iii # II SEAL " ISLAND · mm mm mm mm m m mm m im mm mm mm TX,£AST EXXON OCS -0176 _ i iM m -- -- AMOCO 0CS-0180 Seal # 4 S/T#2 SHELL ET AL 0CS-0181 Seal :tt3 LOCATION PLOT- Amerada Hess Corporation, Northstar No. 3 Exploratory Well Application for Permit to Drill, Alaska Oil and Gas Conservation Commission ONE MILE NORTEC A DIVISION OF 750 WEST SECOND AVENUE, SUITE 100, ANCHORAGE, AK 99501 August 20, 1987 Alaska Oil and Gas Conservation Commission 3001 Providence Drive Anchorage, Alaska 99501 Regarding: Application for Permit to Drill, Amerada Hess Corporation Northstar No. 3 Gentlemen: We are forwarding herewith the original and two above referenced application on behalf of Corporation. The required filing fee of $100.00 is copies of the Amerada Hess attached. The application and supporting documentation 3-ring binder plus three stand alone volumes. is presented in the If you have any questions or require additional information, please contact the undersigned at your convenience. Thank you for your expeditious review of this application. Yours very truly, NORTEC, A Div~ion of ERT Robert C. Gardner Manager Alaska Operations cc: C.R. Richard, AHC Larry Dinneen, AHC RCG/mlb RECEIVED Enclosure AUG 2 ~4 1987 Alaska 0il & Gas Cons. Commisslon Anchorage AUG ~ TM ~t Na~ka 011 & Gas Cons. Commission ~?J~.,,k~'~¥~ Oil & stmtlllmtgeCommiss[or~ A~c, horage ALASKA · CALIFORNIA · COLORADO ° ILLINOI~ ° MASSACHUSETTS ° NEW JERSEY · PENNSYLVANIA · TEXAS · WASHINGTON RMERRDR HESS CORPORRTILIN P. O. BOX 2040 TULSA, OKLAHOMA 74102 918-599-4200 July 7, 1987 Mr' L. A. Dinneen 2744 Iliamna Drive Anchorage, AK 99517 Re: Alaska Representation Amerada Hess Corporation Dear Larry: This letter authorizes you to act as Amerada Hess Corporation's agent and representative for the purpose of securing and executing permits for planned Northstar drilling during 1987-1988 on leases No. BF46 and BF47 in the Beaufort Sea. Sincerely yours, M. B. Bianchi Senior Vice President U.S. Exploration & Production CRR/yb APPLiCATiON FOR (2O ACC AMERADA HESS PERMIT TO 25.005) CORPORATION NORTHSTAR N;O. 3 EXPLORATORY WELL (CONFiDENTiAL) ALASKA O~L AND AMERADA Prepared for GA S C ON SERV~TION AND HESS CORPO,F~AT~ON APPLICATION FOR PERMIT TO DRILL (20 ACC 25.005) AMERADA HESS CORPORATION NORTHSTAR NO. 3 EXPLORATORY WELL (Confidential) prepared for ALASKA OIL AND GAS CONSERVATION COMMISSION AND AMERADA HESS CORPORATION NORTEC/A DIVISION OF ERT Anchorage, Alaska 1.0 2.0 3.0 4.0 5.0 6.0 7.0 8.0 9.0 10.0 TABLE OF CONTENTS TRANSMITTAL LETTER AOGCC FORM 10-401 LOCATION PLAT DRILLING PROGRAM 4.] Supporting Documentation DIVERTER SYSTEM BOP SYSTEM DRILLING FLUID PROGRAM ESTIMATED TIME VS. DEPTH PLOT SHALLOW GEOHAZARD REPORTS 9.1 Shallow Seismic Anomaly Report 9.2 Seabed Survey STAND ALONE VOLUMES 10. 1 Geotechnical Report 10.2 Plan of Operations ~10.3 H2S Contingency Plan NORTEC A DIVISION OF r.:RT 750 WEST SECOND AVENUE, SUITE 100, ANCHORAGE, AK 99501 enuironmet~ta[ and vn,g[neer[n/4 excelle'nce AuguSt 20, 1987 Alaska Oil and Gas Conservation Commission 300] Providence Drive Anchorage, Alaska 99501 Regarding: Application for Permit to Drill, Amerada Hess Corporation Northstar No. 3 Gentlemen: We are forwarding herewith the original and two copies of the above referenced application on behalf of Amerada Hess Corporation. The required filing fee of $100.00 is attached. The application and supporting documentation is 3-ring binder plus three stand alone volumes. presented in the If you have any questions or require additional information, please contact the undersigned at your convenience. Thank you for your expeditious review of this application. Yours very truly, NORTEC~, A '~.~ion of ERT Robert C. Gardner Manager Alaska Operations cc: C.R. Richard, AHC Larry Dinneen, AHC RCG/mlb Enclosure RECEIVED AUG 2 ~ ~/' Naska 0il & Gas Cons. Commission Anchorage ALASKA · CALIFORNIA · COLORADO · ILLINOIS ° MASSACHUSETTS ° NEW JERSEY ,, PENNSYLVANIA ° TEXAS ° WASHINGTON NORTHERN TECHNICAL SERVICES INC. PH. 907-276-4302 750 W. 2ND AVE., SUITE 100 ANCHORAGE, AK 99501 1258 PAY TOTHE ORDER OF., 19-~.-~- 89-6/1252 First National Bank ~ ~'-~/ ,.oo ~ ~ ss,,. ,: ~ ~ 5 ~ooo~o,: o ~ ~ ~ ~ ~ ~,,. OPEN ~.cs-ot 79 ~ ~ NORTHSTARTM -~ ~ NORTH STAR"-!.SLAN D NORTHSTAR NO,2 AMOCO 0CS-0175 BEAUFORT SEA AM ERADA HESS BF-46 AMOCO OCS -0179 Seal#4 S/T#1 428~' LOCATION: ~ 0 NORTHSTAR NO. 5 70°30'41.8'' ~LAT ,5'- 148°46'2.2'' LONG~~O0' S~.~l #1 Y: 6,O38,273,87 '~ Seal t~ 4 ,,?' Orig. Hole ;/,' ,;! ,u X = 650,630.26 ASPC ZONE 4 AMERADA HESS BF-47 · SEAL " ~SLAND ", · · ADL 31279cJ Ii ii iii i i i i iiiiii i I i TX. EAST BF-56 ,, EXXON : OCS -0176 ', ; : ; I I AMOCO OCS-OI80 Seal II 4 S/T # 2 SH ELL ET AL OCS-OlSl i2:-... Seal \ . , \ Sea~2 ',,~ ~Or ig. Hole · " ;eol ~t.3 LOCATION PLOT- Amerada Hess Corporation, Northstar No. 3 Exploratory Well Application for Permit to Drill, Alaska Oil and Gas Conservation Commission I ! I i I ONE MILE AMERADA HESS CORPORATION NORTHSTAR NO. 3 EXPLORATORY WELL (Straight Hole) Program Basis 1. Hole Sizes, Casing, and Casing Points Hole Size Casing D..e.s.crip.tion Programed Casing Points 26" 17 1/2" 12 1/4" 8 1/2" 20", 133 lb, K-55, BTC (Conductor) 13 3/8", 72 lb, L-80, BTC (Surface) 9 5/8 ", 47 lb, L-80, BTC (Intermediate) 9 5/8", 53.5 lb, S-95 BTC 7", 26 lb, NT85HSS, BTC (Liner) Minimum 427 ft KB 3,000 ft KB 10,700 ft KB 11,350 ft KB · The well will be drilled from the Glomar Beaufort Sea I, Concrete Island Drilling System (CIDS) , using Parker Drilling Company Rig 217. A detailed description of the CIDS and Rig 217 is contained in the Plan of Operations which is submitted herewith. · The maximum anticipated mud weight is 11.3 ppg at the · Kingak Shale interval. · Maximum anticipated pressure at TD = 5,607 psi (based on well data in Northstar - Seal Island area) . Maximum anticipated surface pressure = 3,904 psi based on column of gas to surfaCe. Gas gradient = 0. 15 psi/ft. · This well will test the Ivisha~ formation. Estimated formation tops: · Prince Creek/Schrader Bluff - 4,500 ft ss Pebble Shale - 8,100 ft ss Cretaceous Unconformity (Kuparuk) - 8,350 ft ss Kingak shale Sag River Ivishak TD - 9,700 ft ss -10,725 ft ss -10,910 ft ss -11,265 ft ss (11,350 ft KB) · Requested Variance, 20 AAC 25.030 (b) A verbal presentation describing the Northstar No. 3 project was made to the AOGCC commissioners and staff personnel on July 16, ]987. At that meeting, the elimination of the structural casing (20 AAC 25.030 (b) (1) ) was discussed and agreed to by the commissioners. The conductor casing described in this program will extend the required 300 feet below mudline (20 AAC 25.030 (b)(2)). Due to the weakness of surficial sediments in the Beaufort Sea, Amerada Hess Corporation hereby requests a variance from 20 AAC 25.030 (b) (3) requiring a leak-off test immediately below the conductor casing. Amerada Hess Corporation requests that this requirement (limited to the conductor casing string only) be waived for this well and any subsequent drilled from this location~ using similar casing programs. · Downhole Disposal of Drilling Fluids Amerada Hess Corporation may wish to dispose of drilling fluids by injection down the 13 3/8" x 9 5/8" annulus. A General Wastewater Disposal Permit (Number 8740-DB002) has been issued by ADEC covering this activity. Prior to any actual injection of drilling fluids, the operator will meet all requirements of 20 ACC 25. 252 relating to the underground disposal of waste fluids. STRAIGHT WELL DRILLING PROGNOSIS Operator: Lease & Well: Surface Location: Bottom Hole Locaton: Proposed TD: Water Depth: AMERADA HESS NORTHSTAR 93 Latitude: 70° 30' 41.87 Longitude: 1480 46' 2.2 STRAIGHT WELL 11,350' 43 feet ae Drilling Procedure I · · Move in and rig up Concrete Island Drilling System (CIDS). Conduct spud meeting with all personnel on board rig. Coordination with all personnel will be essential. This should include H2S safety training. Pick up 17-1/2" bit, 26" hole opener and stabilizer. Drill 26" hole to ~427' RKB; 300' BML as per Bit and Mud Programs. · Take Totco survey. Circulate and condition hole for casing. Pull out hole. e Run 20" X 5/8" W.T. conductor casing as per Casing and Cementing Programs. Use double valve stab-in float shoe. · Run in hole with stinger on 5" drill pipe and stab in. Establish circulation. Circulate hole clean. Mix and displace cement as fast as practical. 6. Pull stinger out of hole. · Cut 20" off at desired height. Weld on 21-1/4" 20009 flange. Rig up PVT, flowshow, gas detector and all monitoring equipment. (See H2S section for special H2S procedures) . · Nipple up 21-1/4" diverter system on 20" structural pipe. Function test diverter. Nipple up bell nipple and flow line. 10. Pick up 17-1/2" bit and stabilizer. Function test diverter. Drill 17-1/2" hole to ~3,000' RKB as per Bit and Mud Programs. Take single shot surveys at · 500' intervals while drilling. Start mud logging when drilling out below 20" casing. (See Mud Logging Section for exact specifications). 11. Make wiper trip. circulate and condition hole for logs. Pull out of hole. 12. Rig up loggers. Run logs as per Logging Program. Make clean up trips as necessary. 13. Rig down loggers. 14. Make wiper trip. Circulate and condition hole for casing. Pull out of hole. 15. Rig up casing crew Pick up and run 13-3/8" 72 09 · ~ · ~ ES0, Buttress surface casing as per Casing Program· Utilize a minimum of 5 centralizerS. Use a tag-in baffle collar and double valve float shoe· Install baffle collar on top of bottom joint· 16. Run in hole with stinger on 5" drill pipe and stab in. Establish circulation. Circulate bottoms up. Mix and displace cement as per Cementing Program. Displace cement as fast as practical; pumping slurry until cement returns reach surface. 17. Pull stinger out of hole. Wash out cement to ~25' BML. Grout if necessary. 18. Wait on cement 4 hours. Pick up 21-1/4" diverter. 19 Make final cut on 13-3/8" casing Install 13-3/8" · · W SOW X 13-5/8" 5,000 psi Bradenhead at ~97' above mud line. Test wellhead to 50% of casing collapse prior to nippling up BOP's. 20. Nipple up 13-5/8" 10,000 psi BOP stack and 5000 psi Hydril. Test BOP stack to 5000 psi and 250 psi. Test Hydril to 3500 psi and 250 psi. 21. Pick up 12-1/4" bit. Go in hole and test casing to 1,500 psi prior to drilling out. Install and utilize wear bushings throughout the well. 22o~ Drill c .lent, baffle collar, float ~hoe, cement below shoe if any and 10' of new hole. Circulate cement and cuttings out of hole. Dump all cement contaminated mud. Perform leak off test. Expect 12.5 ppg equivalent. Anticipated mud weight at 'next casing point is 11.5 ppg. Squeeze if necessary or upon instructions from project superintendent. See Cement Program and squeeze recommendation. 23. Drill 12-1/4" hole as per Bit, Mud, and Hydraulics Programs to ~9,700' (Top of Kingak Shale). Take single shot surveys at ~500' intervals while drilling. 24. Make wiper trip. Circulate and condition hole for logs. Pull out of hole. Strap drill string on trip out of hole to log. 25. Rig up loggers. Run logs as per Logging Program. Make clean up trips as necessary. 26. Rig down loggers. 27. Drill 12-1/4" hole as per Bit, Mud, and Hydraulics Programs~ to ~10,700' (Top of Sag River). Utilize an MWD or RLL resistivity tool while drilling the Kingak Shale. No other logs will be run over this section. Take single shot surveys at ~500' intervals while drilling. Extra care should be taken when tripping through the Kingak shale. The Kingak shale is highly fluid sensitive and should be disturbed as little as possible. Test BOP's weekly as per AOGCC regulations. ¸28. Circulate and conditon hole for casing. Pull out of hole. Install 9-5/8" casing rams. 29. Rig up casing crew, pick up and run 9-5/8", 47.0~, N80 and 53.50~, S95, Buttress intermediate casing as per Casing Program utilize a minimum of 10 centralizers. Utilize a. double valve float shoe and landing collar. Install landing collar on top of second joint. See Casing Program for centralizer placement and casing configuration. 30. Rig'up cementers and establish circulation~ Cement 9-5/8" casing as per Cement Program. Use two plugs and displace cement as fast as practical. 31. Wait on cement. Pick up BOP's and install slips on 9-5/8" casing. Hang full weight of 9-5/8" casing on slips. 32. 33. 34. 35. 36. 37. 38. 39. 40. 41. 42. 43. 44. 45. Make r ~h cut on 9-5/8" casing. Nipple down BOP stack. Make final cut on 9-5/8" casing and install 13-5/8" 5,000 psi X 11" 10,000 psi B Section casing spool. Test wellhead to 50% of casing collapse prior to nippling up BOP's. Nipple up 13-5/8" 10,000 psi BOP stack and 5000 psi Hydril. Test BOP stack to 7500 psi and 250 psi. Test Hydril to 3500 psi and 250 psi. Install wear bushing and utilize same throughout turnkey operation. Pick up 8-1/2" bit and bottom hole assembly. Go in hole to top of cement. Test casing to 2675 psi. Drill cement, plugs, landing collar, cement, float shoe, cement below shoe if any and 10' of new hole. Circulate cement and cuttings out of hole. Dump all cement contaminated mud. Perform leak off test. Expect 14.0 ppg equivalent. Anticipated mud weight at TD is 10.0 ppg. Squeeze if necessary or upon instructions from project superintendent. Retest as necessary. Drill 8-1/2" hole to 11,350' as per Bit, Mud, and Hydraulics Programs. Conventional cores will be taken through the Ivishak (~10,912' to ~11,142'). See Coring section for details on the core barrel and bits. Make wiper trips as necessary. Make wiper trip at TD. Circulate and condition hole for logs. Strap out of hole. Rig up loggers and run logs as per Logging Program. Make clean up trips as necessary. Rig down loggers. Make a wiper trip. Circulate and condition hole for logs. Pull out of hole. Rig up casing crew, pick up and run 950" of 7" 26% NTB5 }{SS, Buttress production liner to a depth of 11,350' (300' of overlap in 9-5/8" casing). (See Liner Section for exact details). Set and cement production liner (See Liner Section for exact details). 46. 47. 48. 49. 50. 51. Clean out cement to top of liner with 8-1/2" bit. Test top of liner to 2600 psi. Squeeze and retest if necessary. Pull out of hole. Clean out liner to landing collar with 6-1/8" bit. Test liner to 1000 psi. Pull out of hole. Run continuous Gyro survey. Turnkey complete. Perform testing and daywork operations as directed. Return %o turnkey for P & A if so directed by Operator (See P & A procedure). B . Hole Size 26" 17-1/2- 12-1/4" 12-1/4" 8-1/2- Mud Program Depth 0- Mud Type 427 Sea Water w/sweeps 427 - 3,000 Low Solids Non Dispersed 3,000 - 9,700 Low Solids Non Dispersed 9,700- 10,700 CLS * 10,700- 11,350 CLS* Weight pH W~.... 8.8-9.0 9.0-9.5 N/C 8.8-9.5 9.0-9.5 N/C 9.0-9.5 9.0-9.5 6-8 9.5-11.5 9.0-9.5 2-4 9.5-10.0 9.0-10.0 3-6 Actual mud properties will be dictated by hole conditions. * Disperse only if necessary to control rheological properties. C . Electric Logging Program 1. Surface Hole Interval a. Long Space Sonic/Dual Induction/Gamma Ray/ Caliper/Spontaneous Potential 2. Intermediate Hole Interval (To Top of Kingak) a. Long Space Sonic/Dual Induction/Gamma Ray/ Caliper/Spontaneous Potential b.. Litho-Density/Compensated Neutron/Natural Gamma Ray Spectrometry c. Electromagnetic Propagation/Microlog d. Dipmeter e. 45 Sidewall Cores (On one attempt only) · Kingak Shale Interval a. Bariod Recorded Lithology Downhole Logging Tool (RLL) or equivalent (Resistivity/GR) 4. Total Depth Hole Interval a. Long Space Sonic/Dual Induction/Gamma Ray/ Caliper/Spontaneous Potential b. Litho-Density/Compensated Neutron/Natural Gamma Ray Spectrometry c. EleCtromagnetic Propagation/Microlog d. Dipmeter e. Repeat Formation Tester (One run) f. Vertical Seismic Profile 5. 7" Liner Interval a. Continuous Gyro Survey Coordination and cooperation with Operator's personnel in obtaining geological information will be necessary for efficient operations. This is especially critical at the 9-5/8" casing point. The drill string will be strapped out of the hole at all logging points. Field tapes should be provided to Amerada Hess after each run. A composite tape needs to be made, after completing the well~ A tape of the MWD or RLL logging run should also be provided. D~ Mud Logging Program 1. Install mud loggers upon setting structural casing. 2. Start mud logging at ~427' and maintain until total depth. 3. A mud log will be telecopied daily to A.D.T.I. (713) 266-9195. 4. See Mud' Logging Section for details on sample catching and distribution. E. Recommended Bit Program Measured BIT Depth Recom. ~ Interval WOB 1 0- 427 0-25 Size Type 17-1/2 X3A w/26 HO 2 427-3000 17-1/2 X3A 10-25 150-200 30 3 3000-4500 12-1/4 X3A 25-40 150-200 40 4 4500-5800 12-1/4 x3a 25-40 150-200 40 5 5800-7000 12-1/4 X3A 25-40 150- 200 40 6 7000-8000 12-1/4 X3A 25-40 150-200 40 7 8000-8800 12-1/4 X3A 25-40 150-200 40 8 8800-9500 12-1/4 J-2 25-40 80-120 50 9 9500-10,000 12-1/4 J-2 25-40 80-120 50 10 10,000-10,400 12-1/4 J-2 25-40 80-120 50 11 10,400-10,700 12-1/4 J-2 25-40 80-120 50 12 10,700-10,912 8-1/2 J-2 20-35 80-120 50 13-16 10,912-11,142 8-1/2 MC201* 10-25 60-110 ** 17 11,142-11,350 8-1/2 J-22 20-30 110-150 40 Recom. Max. RPM Hours 150-200 10 * Diamond core bit. ** Check core bit for wear before each coring run. F. Hydraulics Hydraulics should be calculated to achieve maximum impact force. Flowrates should be adjusted so that laminar flow occurs in the drill Pipe open hole annulus. The change point from laminar to turbulent occurs for fresh water muds at about 140 feet per minute annular velocity. This will vary some with mud rheology. Turbulent flow is unsatisfactory for optimized drilling and hole conditions. High equivalent circulating density, lost circulation, washed out holes, poor quality logs and bad cement jobs are some of the results of improper hydraulics. The following guidelines are offered as a range of flowrates that should be satisfactory. Hole Size Min. Flowrate/A.V. Max. Flowrate/A.V. 17-1/2" 860/75 1,600/140 12-1/4" 380/75 720/140 8-1/2" 140/75 270/140 Use of hydraulics program to maximize hydraulic horsepower or impact force is acceptable. Flowrates should be modified between a minimum of 75 annular velocity and a maximum of 140 annular velocity across drill pipe in order to do this. Ge Solids Control Run high speed shale shaker, desander, and desilter during the entire well. Use centrifuge as necessary to control mud properties. Never utilize drill solids for weight control. I · J · Drills and Tests. 1. Test BOP's as per AOGCC state requirements. 2. Pit Drills will be performed and recorded as per AOGCC requirements. 3. Abandon Ship Drills and Fire Drills will be performed as per AOGCC and Coast Guard regulations. 4. H2S drills will be performed as per AOGCC regulations. Reports 1. Morning Drilling Reports (see sample) and Mud Log will be prepared as of 0600 hours each day. They will be transmitted to the Project Superintendent between 0600 and 0700 hours each day including Saturday, Sunday and holidays. 2. A daily inventory of drilling mud components and fuel shall be maintained. Daily variable costs will be included in each Morning Report. Contact Lists 1. A.D.T.I. 2. Amerada ~ess Corporation 3. Shorebase Dispatcher 4. Service Companies ACTUAL CASING* TO BE RUN STRAIGHT WELL CAS lNG DEPTH S I ZE FROM TO FEET WE I GHT GRADE THREAD ,, 13-3/8' 0 3,000 3,000 72.0 L80 BUTT 9-5/8' 0 3,300 3,300 47.0 N80 BUTT 9-5/8' 3,300 10,700 7,400 53.50 S95 BUTT 7' 10,400 11,350 950 26.0 NT85HSS BUTT *ALL CASING MEETS OR EXCEEDS THE CRITERIA SET OUT IN THE DETAILED CASING DESIGN SHEETS. DEPTH (FEET X 103) 10 11 MUD WEIGHT .9.5 I MUD GRADIENT .494 PSI/FT BUOYANCY FACTOR 0,~548 TOP OF CEMENT $U1:~ FT FORMATION FRAG GRADIENT 0.65 GA5 GRADIENT · 15 PSi dFT NEUTRAL POINT IN MUD : 25_64: FT PSI/FT _ 3000 _FT OF 13--3/I~. OD CASING F OR ~_,AuD-o!~ s~ , , NEX2 CASING 9-5/8" AT 10,700' W/TH 11.0 PPG . ....... COLLAPSE' " BURST .... .... FRACTION NYDRO- - - ' DEPTH,, ,, , . ,, ,. , ...IG ,,, ,, RATED OF IJSEA~,,! STATIC DESIGN RATED LOAD DEIIGM A D FROM TO FEET WEIG~I GRADE I##EAD SECTION CUMULATIVE B~OYED-T~) PSi RATED PSi PSI FAGIOII PSI PJJ FACTO# LBS IDJ FACTOR 3000 .... 0 30°0 '72.0 r,8o , Btn~, 216000 :~16ooo 184..6'~7 2670 100% 2670 14.8.2 ,,1.80 5380 1500 3.,59 !650 7.64 ALLOWABLE PULL 400,000 . LBS. MINIMUM INTERNAL DIAMETER~,.,.~IN. MINIMUM DRIFT DIAMETEIi _12,25 IN. MAXIMUM ,JOINT OD.~IN. Br: ~K. ~ . , _ ~AFE.' 7-1-87 DEPTH TA a T,~/-,4 I( WOK' T 8[.O,.e' ~ - , , LOAD. Il II I I II II I I I I I I I I I · II II I ! II I II III I I I I I IIII ii i i iiiii i i i i i i ii · i i 72.0# 3300 F2. FOR INSPECTIC~ PIPE _ FEET . o,,,,,;,.o.. '"'0' "' $/rr ;o,,,. L80. ~ 3000 30 3030 i il i il i i ,, ,11 ,J I i iJ II I ~1 I TOTALS 3000 30 3030 , " ~URFACE CASING CONFIGURATI PRALIZERS--- .JOINT. -- Jo I . BACK OFF-AND · LOCK -BOTH , , ;NTP~-L~ SIDES'.DF,CC* j 3'.INSTALL CENTRALIZER i BACK OFF. AND ~HREAD LOCK BOTH---- SIDES'.DF. f~C,~2 INSTALL CENTRALIZE.t 1 -~TOP: RING '~D C~TP3LIZ~L~/ "' MIDDLE 'OF JOINT I' ~~DL~~"~D; P~KSTA~LED B~LE CO?R O~_ BOTOM OF JOINT ,2 .............. .__.~;~ ~. 5~ ...... - ~o~. ~~-~' :t --' RING ~D~ CENT~IZER lO FT.-- ~.o~- ~o~,---I, . ,, ~ ........... ~og:.~:.~: g~~~z~, !.0'. ~o~. ~o ~~D"~" p~'S~zD ~o~ s~Os ' .DOqBLE :FLOAT ' ' SHOE MUD WEIOHT ll.b _ .c ,i, MU D GRADIENT,, 0.572 PSi / FT BUOYANCY FACTOR .8319 TOP OF CEMENT 7100 *FT FORMATION FRAO GRADIENT O' ,728 GAS GRADIENT -15 .... PSIIFT NEUTRAL. POINT IN MUD' 8_90].: FT PSI/FT I! 10,?00 FT OF 9 5/.BIN' OD CASINO FOR ]~,A~~ ssa .... NEX~ CASING 7" PI~}DUC~ION I~-2 AT 11,350' WITH 9.5 PPG . .. cOLLAPSE BURST ' -- -,,, FllACTK]N HYDRO- __TEN DEPTH ' WEIGHT RATED OF USEA~I,.ESTATIG I)~SliN RATED LOAD DEII~N RATED DESIGN ' ,,,m . rill IIll n II I I Ill,Il t I I n FIK)M TO FEET WEIGHT!' GRADE IlMIEAD SECTION CUMULATIVE #,UOVED-Ib PSi RATED PSi PSI FACTO# PSI Ix3J FACTOR LBS lO*~ FACTOR 10700'7000 370'0 47.0s595~ 173900173900144667710b100~~7100 6"i20 i'.1'6' 6870950'7 2311sq '6'.64'' 70001 ,,0"~06'0'47.0 I. B0 BUI'I'" 35-9009.. 5020000 4,18363 4,766 95.7% 45.55 4004 1.14 6,870 -3904 ,1.,.76 1086 2.1,6 i i ii i Il I I I ........... ~,, , i il i : il , · i i i L i i,,, i i,i j ' · - r ,i I I I I I II II II II I I F = ~/A - fi'Or K BL ALLOWABLE PULL 450f000 LBS. MINIMUM INTERNAL DIAMETER.,8' 681~ IN. MINIMUM DRIFT DIAMETER 8_.525 IN. MAXIMUM .IOINT OD,. ,1.0.625 IN. BY'.* ~ K. RENFRfM DARE: .JULY !, 1987 . DEPTH TI~ A TI~/A .... ff fi'Dff ' 'T B£ND,#~ 1 ...... LOAD i ! ii ii i ii ii iii ii i i i i i i i i ii _ i i ii · i 9 5/8", 47.0 9 5/8", 47.0 i o,sc,,,,!o,, ,,,o[ u,,, so,,~,A,, .,~.83.~1, $//~r TOm. SS95, BUrlT 3700 37 373,7 L80, BLTI~ 7000 ~.Q . 707,0 , I ,, TOTALS10,700 107 10,807 . ' ' ' {' '" ' ' ; : I ' ' i. '9' "': NTE D E':CASING NFZGURAT2; N · , . ,. :.. ~ , , ,,,. ' ~, ' ' ': * i ~ , . . . · I · ~' · .~ . ~ : ...... ~i .i . . . ~ , : : ~ '~',r' i , ~' ' ' ~ ' - · ' ' ' · . ~ ' ~'; , . ' ~ , : 11~1 .... f ~' ' ~ ' : i ~ ~i 'i ' · ' , [ ,, ,, I, - l~. ~i",. .j~:,, :"T.; :;"r ': . ;. ~ ,, ,- ., :;,' [' : ~ ~ ~ ; ' 'i : ~ ~ ~ : ; I . . ~ , I ' i i , · ; . ~i ; , ~ i ~ . , : ~ · '"' . _ ~ . .... ~ ~ . ~ ..... , ~ ~ , : , ., ,~ z ~ON ~V~RY ~OTHE~ · . · ~ , ~ _ ~ ' ' ~" , 'JOINT-FOR~ :~ ~o~ ~-~'o':~~; ' _ . - . . ; ;~.; , '; '. ..... , · : ' I ~ ' , ~ ' , .... . . ', : ; ; . ' ~ . ~ , ' ~ ._ ,; . ,: ~ t , , , · .... ........... .., ~,,~sAD_ ... :.. ., :,. ~ : ~c~.aO~._S::~s~'~ .., ~ , ~ ' . ~ ' ,, , ,,: ~ : : .-~) ~ - : ~ ~.. .,, ;, :.:,, ~l~ i ' - L ~ : ' ' ~ . ~ · ; .... . : ~,i , , ] , . , . ,. : , _ ; ., ' : . ~ : . ' . , ~, ~, , ~ , '. ~ ~ . ~,, ... _ .... , ' ', ; ' ' ' -~s~-~~~ , ~ ,,, ,,..~., ~i,,... :..:,,. . . . ........ . . .,, ,~ ~ ' u ,, ,, . , ~ ~,~1 , ;.' . · , ....... , ,, . , ,, . _.. c~sz~' c9~a~ ,~ , ;" ,,,'.[ _'.2 ~ . ' ~, ........ . . . ..... iNSTALL. (',ZNT~tZE]~ ' ~ , ~" ~ . . ' ' " ' T ' · I' · " ' '. : ~ ' ' .... , ,.. ~ ..... , ..... ~ . - ..~ ~ ....... ~ ~ ~ .... ;"~"; ,. ,~ ....... .?' ,; "_.:.~ ~ ~-"t ~ ~~D"~OC~: ~O~:.~S;~'.J' : ~'" '. ' :, ,r~i~ . -., :-~'~'; ' '~: : ~~- ,. ;~-~;~.. -,. .,-;~;- ~, 2 · ~ .... Z._I i I ; 'l F i ' ': :". ; , ': ' ,i~ ; : ' · '; ' ; ~ 'i : ..... ~ ' ' · ____' ; I ' · r ! ' ' L ' i t i t '.- ; ......... ;'~ ......... I ' :i-,',. ,, ; ,. :. ;' : ..-~p.. .; :':", .': ~', ; ..... --~FLOAT CHOE-TY~E:~O-DV--- ~_/i~~_~_~~ :FLOATLSHCE :; ] ;,:%:E:: ~~,.: ~ ~ ~ ~ ' ~: ~: ::::~ ~:: ~;-:~:.I ......... ~ ................. ~,., · _ :. ~ ~ ;~,,-2X..~ ,, -" !;7:::4 ..... ~ ~ i .,, . ,,, , . . , MUD WEIGHT 10. MUD GRADIENT~ PSIIFT BUOYANCY FACTOR .8395 TOP OF GEMENTT'~ FORMATION FRAG GRADIENT,, 0.65 PSi/FT GAg GRADIENT 0.15 ,, P$1/FT NEUTRAL POINT IN MUD 965,,~ FT 950 FT OF 7 _IN. OD CASING FOR.. RFAUFOR~ R~A . PBODLLTION LINER ..... COLLAPSE .... BURST . ......... ..... FRACTION !HYDIIO- DEPTH WEIGHT RATED O~ USEABLE STATIC DESIGN RATED L~D ~8~ II I I ~ IIIII I III I filL I III ii ii ii ii f~ TO FEET WEl~T GRADE I~AD SEC/ION CUMULATIVE BUOYEO-T~ ~l RATED PSI ~1 F~I~ ~1 ~ FAG/~ LBS~J F~TOH I ~ II i i i i ii i i iiii i ~3se ~0400 ~sO ~6.0 ~sS ~ 24,709 24,700 20,736 ssso i00~ . ssso' ~i~5 0.~0' 76~0 '"** 666 27.0~ i ..... I I I I, ill I Il lU I I ~ I I I III III I I I I ...... ,, II III II II I I II II II I I III , I III I I I I ] II [ I I I ALLOWABLE PULL .~O0,OC~O LBS. MINIMUM INTERNAL DIAMETER.~IN. MINIMUM DRIFT DIAMETER 6'151~1N. MAXIMUM ,JOINT OD.7-(55,6 , IN. Il UI i i DARE; 7-1.~7 . DEPTH ''Fa "al Fa/al~'' A" W~)~i" F .... B£NOING' ' ................ LOAD II II I Ill I I ~ Il , , II I I ii ii I I IlL I I I II i i III i III ii ! II I II I II i i I I · i I I · 26.0# ** DUE TO NORMAL PRESSURE PRODUCING ZONE, LINER S~0ULD NOT SEE ANY APPREEI~ BURST LOAD. NTB5. ~SS. BL'i~ 950 10 960 .. ; Il I IJ I Ill I II I II I I II I I II I r I I I I I , TOTALE 950 10 960 . CEMENT PROGRAM STRAIGHT WELL 20" SURFACE CASING Well Conditions: Casing size & wt. Hole size Depth Top of Cement 20" 26" 300 ' BML mudline Excess Calculated Mudweight BHT (Static) BHT (Circ.) 100% 8.6 ppg 32 deg. F 40 deg. F SLURRY RECOMMENDATION: (100% excess = 450 Cuff) Innerstring Cement Method Recommended Preflush: Slurry: SLURRY PROPERTIES Slurry Weight - PPG Slurry Yield - Cuft/sk. Mix Water - Gal./sk. 10 bbl H20 Cold set II Slurry Volume = 900 Cult PREFLUSH 8.40 936 sacks SLURRY 14.95 .961 3.89 13-3/8" INTERMEDIATE CASING Well Conditions: Casing size & wt. 13-3/8" Hole size 17-1/2" Depth 3000 ' Top of Cement mudline Excess Calculated Mudweight BHT (Static) BHT (Circ.) Last casing set at 100% 9 ppg 55 deg. F 50 deg. F 427' (20") SLURRY RECOMMENDATION: Innerstring Cement Method Recommended Preflush: 10 bbl H20 Slurry: Cold Set II Slurry Volume = 4362 Cuft 4540 sacks SLURRY PROPERTIES Slurry Weight - PPG Slurry Yield - Cuft/sk. Mix Water - Gal./sk. PREFLUSH 8.40 SLURRY 14.95 .961 3.89 9-5/8" INTERMEDIATE CASING Well Conditions: , Casing size & wt. 9-5/8" 478 Excess Calculated 35% Hole size 12-1/4" Mudweight 11.5 ppg Depth 10,700' BHT (Static) 200 deg. F Top of Cement 7,700' BHT (Circ.) 140 deg. F Excess over Last casing set at 3,000' (13-3/8") caliper recommended 15% SLURRY RECOMMENDATION: Preflush: Slurry: Slurry Volume = 1322 Cuft 50 bbl H20 1:0:0, 0.75% CD-31, 0.1% R-5, 1 GHS FP-6L * 1150 sacks SLURRY PROPERTIES Slurry Weight - PPG Slurry Yield - Cuft/sk. Mix Water - Gal./sk. PREFLUSH SLURRY 8.40 15.86 1.15 4.97 Retarder as necessary for adequate placement time. This cement mixture may require testing prior to the job. 7" LINER Well Conditions: Casing size & wt. Hole size Depth Top of Cement Liner overlap Excess over 7~ 8-1/2" 11,350' 10,100' 300' caliper recommended 15% Excess Calculated 50% Mudweight 10 ppg BHT (Static) 220 deg. F BHT (Circ.) 170 deg. F Last casing set at 10,700' (9-5/8") SLURRY RECOMMENDATION: Slurry Volume = 295 Cuft Preflush: 25 bbl MCS-4, 10 bbl H20 Slurry: 1:0:0, 3% KCL, 1.1% FL-28, 3% CD-31, 1 GHS FP-6L * 252 sacks SLURRY PROPERTIES Slurry Weight - PPG Slurry Yield - Cuft/sk. Mix Water - Gal./sk. PREFLUSH SLURRY · 9.0, 8.40 15.8 1.17 4.97 Retarder 'as necessary for adequate placement time. This cement mixture may require prior to the job. CEMENTING REFERENCE GUIDE FEBRUARY 1987 PAGE I OF 3 IJ-TITA1 IMTllAL PIINART I~WELL-SCNLll. IIALLllUITO1 WfSTEII IMTEllAL BESCIlPIll PUIFOSE SIJSSTITUI1 SUISTITUTE SUISTITUTE ACCELEIATMS A-2 SO(IILIB Strength D-7~P Econolite Thrifty Lite Iletlltllclte Intensifier A-$L Sill--1 Siliclte Liquid Strength D-75 Econolite L /4(utSafl Intensifier gE-1L A-5 Sod(um Forlitton Protection D-&& SILt Ckloridl & Iondlng Silt A-7 Colchl Accelerotor S-1 Cl|Cllll cie|2 I:~iorldl Chtorldl A-TL Liquid Cl|c|uI Liquid D-T7 Llq~ld CBLcluB Chloride AcceLsrltor Chloride A-9 POt#lid Formltio~ Protection N-I1T PotllllUl Chloride & Iondlng Chlortde A-lO Gypsum Thixotropic Additive D-53 Ce|-lell Quickset or Acceierstor 1ETARDERS l-3 l~liflld #oderitt Tellxroturl HR-& brll.~* LllnO~u[fo~ltl letlrder D-I$1 HR-S· NR-7 I-6 IIKeL LUL letorder/Ftuld Oilcll LVL (0-8) Ollcet LVL Lo~l Additive OilCIL LgL I-! Prllfiltlry letlrdlr for Illd Arctic Celmnt I-I Lllflll lllh Telperoture 0-28 lt-12 Illld letord~r WR-6 Berm . letlrder D-95 NR- 15 Intens i f let WI-7 S-11 Pr~)rletlry Nigh Telperoture D-28 #1-12 Blend letorder WI-6 I-1ZL LIl-t. #oderote Tel~eroturl 0-81! ll-6L lllvtntltlvt Liquid lltlrder Prtnted tn USA PAGE 2 OF S IJ-TITJW NATEIIAL IMTEIIAL IESCIII)TlOll I4]M~LL- SCILUll. SUISTITUTE IALL II~JITMI IUBST l TUTE MESTENII SUIST ! TUTE R- 1SL Lilnfn Previfltmt Eve Liquid Ietsrder D-110 ill-13L Vl.6L 1-17 Orpnl¢/lnOrllnlc Uttrl lligh Tel~returo Retsrdir 0-121 II-ZO Iai- 15 I-ZlL tflflln Pr~wfltit I ye #odirste Temperlture Liquid 8etlrcler D-81R II · 6 L W-2L 1-23L Lllntn Privefltitlve lligh TelCirltUrO Liquid lletlrder 0-110 I1-13L WI-6L F~UIO LOSS AOOITtVI[! FL-$L Liquid Letex and Flltrltlofl Control D-1S Lites Pouder Iofldtng Filtretlon Control D-1S LA-Z CLX-1 FL-lO ffrqN'iitery Ilefld lleduces Fluid Loss it Lou Tel~rsturel Floc D-S9 isled 9 CF.1 FL-19 Proprletlry ledUcel Fluid Loss It Noderlte TMq)erlturil D-60 llled 14 CF-Z FL-ZO Prol)rletlry leducel Fluid Loss it Noderltely Nigh Telpersturil CF-9 Pre~'letery lltld leduce8 Fluid LOll It lil~ TEaENrItUf# lo&id 22_4 CF-lO J~q~rletory lied twos Fluid Loll et Nodlrlto lndNoderltlty IIIh Temperlturel FL-4SL Pf~flet~y lied Liquid Fluid Loss Additive fL-46L PrqJrletery liend Liquid Fluid Lm Additive Isled lOL IIM)e PW letery Iliad Fluid Loss Additive for Extended Slurriel File 0-60 CF-6 fL -S~ PWlltlry LN Fluid LOll Ilelul Extent IJ-TITAI IIATEIIAL lATER ! AL BESC~IPTIQII llllll! lqlPOSl FEBRUARY ~987 PAGE 3 OF $ ~OI~LL-SCILUI. IALLllUITOI UESTEll SUISTITUTE IIJSTETUT! SUISTITUTE !ON0!IG AODITIVES gA-Z9 PltentlCI Iofldtr~ lxpl~tvo Additive SeLf Streli Ges-Chek SA.S6 Propriotory Bonding ifld Gel Control Addttlvt Gll Itek Fig-Loc 1 & 11 gA-61 Proprletlry IIlfld lending end O, ConTroL Additive None lone lone CENENT OlSPERSA#TS C0-31 lllperllflt l~luce$ Cent Viscosity 0-65 CFR-Z TF-4 C0-$IL STIENGTN IEllOGIlSllOI Liquid DIllNreont led~J¢os Cesent Viscosity D'80 CFR-ZL TF-4L I-8 Strength letrogres$ion 0-66 Siticl Flour SF-3 S-SC Slllce Send Strength letrogrellfon 0.]0 Illlce FLour SF-& COlree KXTENOEll OIIllx A letm-ll Pozzotal Lev Olnltty Extender LItI~N)Z 7 POmJX D OIICel O JJmto~Eirth lxt~r Thrifty Nix ledluB Iletiei I loire Ch#lolL Extender 0-79 EconoLite Thrifty Lite Thrifty NIx-L LlquldSodlul IIItcete Liquid Chilice| Extender Econolite l~fltmlte kntenlte lento~lte (O20) gettJbJrtM Get lentoe~nt Fly Ask Lou Oenslty, lcofueice( LitepoZ 3 PO~tIx A Pozo~nt A lOAN PIEVE~TEIS fP-6L PrqJc ietlry (IClutd Foam Preventer 0-4? O-Air Z ~ fP-I Prlprletlry Fm Preventer O-Air I FEBRUARY PAGE & OF IJ-TITAII IIATEllAL II~INART DMLL-SCILLI~. IALLIIIRTOI I~ESTEI# NATFJIAL IESCIIPTIOII PURPOSE SIJIGTITUTE SLIISTITUTE SUBSTITUTE ProprJetlry Foaling Agent Fom Client Foal Cmnt Foam Cement for Cement FOAMIng AGENTS FA-lZ FA-I& Proprietary Foaming Agent Foal Cmnt Foil Cmnt · for Client I~EIG#TIKG #ATERIALS Ilrito brite VoiohtlnO MaterllL 0-31 Ilrlts Barite llmenttl llmel~ite Valghttr~ Nltertli D-18 #l-Dense 2 liaHInlte II~latttl lelltitl Veightfn~ Material 0-76 Mi-Denis 3 Nmtlte SIM ~ ~t~tfng Materiel Si~ iD-30) SIM h~ (OF-4) tGHTWEIGNT ADDITI~S L¥-6 Cetlmlc Lou Density Lite Poz 500 Sp~eretlte Cenospheres S~dlereo Additive BubbLes Lou Oeflatty GLass lubbLel GLIai BubbLes Glass BubbLes Additive L¥-?-& II#l lutd)lel Lov Density GLIli id~)tos GLOSi Id)bios Gills Additive ¥ltlr lid NUCI Thiflning CW-7 NLM FLush I~-1 Surf~ctl~ts Spicer SPACEIS Mud CLean Mud Su~ Patented viscous iofl~ Cepiotlts None BLend S~eep Spicer IMtghted P~lltlry Oenltfled Vticoul Spicer 1000 IAN-S IMd lllll) lid ShOp Spicer ftou ~rd f~mNl~r~d Lost Clrculltiofl MIiIIttvl Spacer ExceIte Gel ftmdGulrd-L Liquid LOlL Circutatiofl Zonecheck fLo~chlck Aqua Fix-1 klditlv~ Spmcer TAg IMTE! EAL Pt !NARY OO~LL- SCNLWl. NATEI !AL BESCR ! Fl !Oil PUIPOSE SI JIlT ! TUTE IALL i ILIIZ~II SIJIIST ! TUTE FEBRUARY 1987 PAGE 5 OF 5 IdESTENI SIJISTITUTE NCS- 2 Proprfotsry Turbulent Flou Bleflcf Spicer Spicer 30o0 Duo( Spicer Turbo. F10 SCS-3 Prol)riotory Turbulent flou Spscor Blond for Oil-Based HUd Spicer 3001 Oust Spicer Turbo. F10 NCS-& Proprietary Continuous Nix Item Spacer for Voter-Based or Oti-Sued SUds Sofl4 NQ~O #ydrollte Proprietary PrifLush for tlend Foi~ed CeB~nt Ilofle Sofl4 Unllul Pro~lotory Itond EBuLIion Spicsr tone SAN-& APl-1 LOST CIRCULATION Gilsontte Grlnulsr Ioturll Lost ClrcuLltton ProventitJvo O-2& SJtlo~lts Gitsonite ~oL Soil Ground Coot Lost Circulation PreventltJve ~oLits Cello Flske CettMone flskos Lost CircutstJon ProventotJve 0-29 FtoceLe Cello Sell Nut Plug Ground Wslnut SheLls Lost Clrculstion Prevontstlve Tuf Plug Tuf PLug Tuf PLuS Perlite ExFended Porllte Lost Clrcuistion ProvontltlVo Perttte Pt#tlc Special ltond Lost Clrculstton PrevefltotJvo NJ-Sell Blind of flberl, flikoo Lost Circulation Mullrimulel Preventative [ilk leal [uik Seal FLex Seat S~red~ lubber Lost Clrculstion Provontitive Zofl4 Chek f~lClll #t lyltll~ Coebit Lost Circutmt ion Polymer PLug Guflk. or leniUl Squeeze Teipo Seat Gypsum Gypsum CKt CMd~lt Loot C! rcui et ion D.S3 Quickset PRODUCTION LINER PROCEDURE STRAIGHT WELL BEAUFORT SEA The following procedure is recommended for cementing the prodUction liner. Note: All displacement volumes should be calculated for the lengths involved at the time of the liner setting. 1. Make a wiper trip. 2. Circulate and condition hole for logs. 3. Drop rabbit and strap out of hole. · Rig up loggers and run logs as per logging program. Check caliper logs for cement volumes. 5. Rig down loggers and go in hole. 6. Circulate and condition hole for casing. · Have liner and cement personnel and equipment on board prior to starting out of hole. Pull out of hole. Lay down Grade E drill pipe so as to match drill string design for drilling below the liner. 8. Make up oil jars on a double of drill pipe. Stand this assembly in derrick. Check and drift all jars. Each should have a big enough ID so that wiper plugs will pass. 9. Rig up casing crew and cement lines. 10. Pick up TIW type CLS-2 down jet double valve float shoe, 3 joints of liner~, TIW regular landing collar and rest of liner (Total of 950' of 7" liner with 300' of overlap in 9-5/8" casing). Clean and threadlock each connection from the liner shoe through the landing collar. Check for circulation on 1st joint after landing collar. Fill each joint as it is run. After the crossover sub or last casing joint has been run, change elevators to drill pipe and rig down casing crew. Run a minimum of 300' of overlap. Run centralizers 10' above the shoe and every other collar for 250'. Centralizers should also be run every other joint from ~ 11,000' to the liner hanger. 11. Pick up and make up type IB Hydro liner hanger, type LG setting collar with RPOB profile, type LN setting tool, and type B retrievable paCkoff bushing with polished extension nipple. Lower liner and hanger into hole to a depth of 11,350'. Remove casing spider and set drill pipe slips on setting tool. Lock rotary and do not turn string to right after hanger is picked up. Pick up kelly and screw into liner setting tool. Break circulation and confirm that the packoff is not leaking. Set kelly back in rathole. Align and lock block. 12. Pick up the stand of drill pipe with jars. The oil jars are in the cocked position and must be bled off before the weight of the liner can be picked up. This will take roughly 10 - 15 minutes. Clean up floor and review the running time with driller. The liner should (because of tight clearances) not be lowered into the hole any faster than 1 ft. per second. Screw into setting tool and carefully guide and lower liner, and hanger through BOP stack. Install drill pipe wiper rubber. 13. Trip in hole with liner on drill pipe. Fill the drill pipe during the trip into the hole using the casing fillup line. Some mud can be put into the pipe each stand. Stop every 10 stands and completely fill the drill pipe. This method will trap less air in the drill pipe than picking up the kelly and will be less time consuming. Stop going into the hole with liner shoe one stand inside of intermediate casing. Rig up plug dropping manifold on a single of drill pipe and place in V-door for use as landing joint. Continue in hole with liner on drill pipe completely filling drill pipe each 10 stands. 14. Upon getting near bottom pick up plug dropping head joint and tag bottom. Attempt to break circulation while slowly moving pipe. If.good circulation is established and pipe moves freely circulate bottoms up slowly. Wash any fill and check drill pipe measurements to establish true T.D. 15. Pick up and slack off slowly to establish string weights. 16. Cement with the following pump sequence as per cement program. The reCommended cement is Class G, .5% Halad 344, .2% CFR-2, .2% LWL. Slurry weight is 15.6 ppg. Note: Cement design should be checked and adjusted as necessary for downhole conditions and results of cement lab tests. a. Pump 10 bbls spacer weighted to 1/~ ppg above mud weight.. Liner should be reciprocated 20' - 30' during circulating, cementing, and displacing. b. Pump cement slurry as per cement program. c. Drop dart to sting into liner wiper plug. d. Pump 5 bbls weighted spacer as before. e. Pump calculated displacement of dart to seat in liner wiper plug. Slow down pump and watch for dart seating. Displace until plug bumps. f. Increase pump pressure to shear wiper plug pins and continue pumping to displace cement and wiper plug down liner until plug bumps on landing collar. Reciprocation of the liner should be stopped 10 bbls prior to seating the dart. g. Continue to increase pressure to 3000 psi or (0.25 PSI/FT X Liner shoe TVD). Hold pressure for 5 minutes. This will set the liner. 17. Rotate to the right eight turns at the setting tool to release the LN liner setting tool. Pick up 5 ft. Note: It Should be apparent that the liner hanger is set by the loss of weight with free travel of the drill pipe. 18. Pull out of hole without reversing out. The increased pressure placed on the formation may cause it to break down. Wait on cement 6 hours. Monitor hole and shut in if necessary. 19. Pick up 8 1/~ bit and go in hole. 20. Clean out to liner top. Circulate hole clean. 21. Test top of liner to 2,600 psi. 22. Pull out of hole. 23. Squeeze, cleanout and retest as necessary. 24. Pick up 6-1/8" bit and go in hole. 25. Clean out liner to baffle collar. 26. Test liner to 1,000 psi for 15 minutes. Squeeze and retest if necessary. Pull out of hole. 27. Run continuous Gyro survey. 28. Turnkey. complete. 29. Start testing and daywork as Operator directs. HYDROGEN SULFIDE DETECTION SYSTEM The area in which the Northstar No. 3 well is being drilled is not known to contain hydrogen sulfide gas in any formation above the Lisburne Formation. Since the subject well will bottom in the Ivishak Formation and not penetrate the Lisburne Formation hydrogen sulfide risk is considered extremely low. Nevertheless a Hydrogen Sulfide Contingency Plan is being prepared as a separate Stand Alone document. Personnel safety is the prime concern of this plan. In the remote possibility that H2S gas is encountered, procedures will be in place to handle the situation. The Hydrogen Sulfide Contingency Plan will thoroughly familiarize all personnel with the following: Training for H2S emergencies including identification of safe briefing areas, Visible H2S Warning System. H2S Detection and Monitoring System. Personnel Protective Equipment. Ventilation Equipment. Metallurgical Equipment Considerations and Adjustments in the Mud Program. Flare Systems. Rig Evacuation Procedures. - The basic~ premise for the protection of both personnel and the environment is containment. In the event of accidental release of H2S gas all safeguards and control procedures will be adhered to by all personnel. The rig will be positioned on location with the bow pointing at approximately 270' (due west). This will place the quarters upwind during prevailing weather conditions. 1.2.2 IO1T H2S SEKS~ ASSDIBLY The I01T H2S sensor assembly consists of · sensor Ind · voltage transmitter housed tn an explosion-proof ~AL outlet box. ~e Figure 1-2. ~e I01T H2S sensor ass~bly ts l~ated tn ·rems ~ere H2S gas ts 11kely to occur, and Js destgn~ to contlnuous]y detect H~ by d~ffuston/adsorptton. ~1s so]~d state sensor ts des~gnK to detect H2S gas concentrations less than 500 parts-~r-btlllon, and ts sen- sJtJve to percent range concentrations of H~. T~e sensor ts not poisoned ~en expos~ to H2S up to 100~, and exper- tences no loss of sensitivity due to the lack of exposure to t~ toxic gas. ~e 101T sensor ts virtually unaffected by t~perature change and h~idlty. The voltage transmitter of the assembly receives the stgnal emitted from the sensor and transmits the voltage signal output b·ck to the controller through a four conductor cable. The voltage transmitter also.permits one man, re~ote calibration of, the sensor. The GUAL housing ts an explosion-proof, conduit outlet box designed to meet Installation requirements in hazardous environments. The housing is UL approved and designed for installation in Class % and Class I! hazardous locations. H ~5 .~ETE AL hT~vl ~/ST~ ~.~,~ 4.~ SPECIFICATIONS $O~ IOIT &2S SEI~SOR ASSDdBLY The s~c~f~cat~ons for the 101T H2S sensor ass~bl~' are 11 sted In Table 4-2. . TABLE 4-2. 101T H2S SENSOR ASSEHBLY SPECIFXCATZONS Type o Temperature Range Sensor Ltfe Znterference Data Interconnect 1/1re Between Sensor and Controller Electrical Class1 ftcatton Response Cleartng Time Range of Sensitivity Pa tntenance of Sensttlvlt2r Poisoning dS t~r Range Solld state, se~t-conductor, diffusion/adsorption type -30 degrees F. to +150 degrees ~aranteed: one year Expected: three years I~ethane..,,,...,,,. No effect Ethane.,,.,..,.,,., No effect Propane, · ,, · · · · · · · · No e f feet Butane,,,...,..,,,- No effect Hexane,,.,,,,.,,.,. No effect Carbon Honoxtde,,.. No effect Sulfur Dioxide.,.,, No effect I~ethyl Parcaptan... 3 to 1 Hydrogen........... No effect up to 18 gauge, 4 conductor... up to 500 ft. 16 gauge, 4 conductor.... up to 1000 ft. 14 gauge, 4 conductor.... up to 1500 ft. 12 gauge, 4 conductor.... up to 2500 ft. Class I, Group C, D; Otv 1 0-10 ppm tn less than 10 sec- onds wtth 50 ppm H2S applted 80'~ tn less than 40 seconds 100~ clear In less than 3 mtnutes Detection of less than 500 ppb up to ~, range of H2S No loss of sensitivity or response ttme due to lack of exposure to H2S Wtll not be potsoned by petroleum gases. Shows no 111 effects tf exposed to 100; H2S over' prolonged pertods of ttme. Ilo effect up to 100'~ · 4.5. Z :) REPLA:EI~ENT OF C~%RCUIT BOARDS Release the panel locking screw from the front panel of the controller. Pull out the control 1er to access to the ctrcutt boards. Pull up on the defective ctrcutt board to renove, the board from the motherboard. Compare the part number of the new ctrcutt board to the defective board to ensure that the new board ts the correct part hubbard 4.$.3 REPLAI:::EHENT OF A SENSOR 3) Disconnect the output power to the defective sensor fr~r~ the controller. 2) Remove the interconnect wtrJng from the defecttve sensor. 3) OJsmoOnt the sensor assembly. 4)~ Securely mount the new sensor on the condutt run or a suitable mountJng bracket ktth the vent opentngs of the sensor headcover/ralnguard tn the vertical posJtJon. A 2-]/4" to 3" clearance behind the sensor ts recommended. $) Connect the interconnect wtrteg to the sensor terminal. 6) Connect the Interconnect wiring to the controller. A calibration procedure must be performed when a sensor t$ replaced. See Section 3. 3.2. 4.6 EI~GXNEERiING DRAI~:INGS The subsequent pages include the following engineering draw- trigs: 3) ScheMatic 0tagram TAC:-689, drawing no. 82A0190 Schematic O~agram for TAC-73X, drawing no 8~803Zl Schematic Diagram TAC-687, drawing no. 8280193 iiSchematic Diagram TAC:-6~8, dra~ng no. 8280~94 Component Layout TAC:-686, drawtng no. 82A0~7 Co~ponent Layout for TAC-687, drawJng no. 8980192 7) Co-portent Layout for TAC-689, drawing no. 828019! Component Layout for TAC:-688, drawing no. 8280195 Component Layout TAC-690, dra~tng no. 82A0198 10) Co~ponent Layout TA:-691, *drawing no. 82A0199 Schematic For 101T, drawing no. 82A0467 C:o~ponent Layout for 101T Sensor, drawing no. 82A04~3 SECTION 3 MAINTENANCE 3.1 MAINTENANCE SERVICE Texas Analytical Controls will provide start-up and/or maintenance service for all TAC products. Other .training and assistance services offered are' l) Introductory 6 hour program in the Stafford plant. 2) Complete 1:6 hour servicing program in the Stafford plant. 3) Field service, on-site repair by a factory technician. 4) Field service, on-site repair by authorized representative, factory trained technician. 5) Quick turn-around repair in the Stafford plant. 6) Quick turn-around repair in an authOrized TAC service center. 7) Assistance with system designs and application. For more detailed information concerning training and assistance services, contact Texas Analytical Controls, 4434 Bluebonnet Drive, Stafford, Texas, (713) 491-4160. 3.2 CALIBRATION PROCEDURE All TAC monitors are shipped calibrated. However, it is recommended that a complete calibration procedure be performed 24 hours after the installation of the monitor. Use a TAC Model 3000A calibrator and calibration adapter, pt. no. TAC-382, to perform the calibration procedure. See Figure 3-1. The calibration procedure consists of setting the zero adjustment to a zero meter reading when no H2S exists in the area of the sensor. Then a known amount of H2S is applied to the sensor. The span adjustment is adjusted to set the meter, reading equal to the rated calibration sample. The calibration procedure is performed as follows: 1) Ensure that the meter reading is zero +1% full scale. 2) If the meter reading-is not within the-specified range, adjust the meter display to zero +1% full scale by adjusting the zero adjustment. To lower the display re-ading, turn the zero adjustment counterclockwise. See Figure 3-2. Ensure that no H2S exists in the area of the sensor. Zero air may be required in areas where a continuous H2S environment exists. 3) Press the calibrate switch to disengage the alarm relays for a 15 minute period. 4) Apply an H2S gas calibration sample of a known concentration to the sensor being calibrated. Allow 1-2 minutes for the sensor to achieve 100% of its reading. Adjust the span adjustment to a meter reading equal to the rated H2S calibration sample. To lower the display reading, turn the span adjustment in the controller counterclockwise. To elevate the display reading, turn the span adjustment clockwise. See Figure 3-2. 5) Remove the H2S gas calibration sample from the sensor. Ensure that the controller meter display clears to zero within 2-3 minutes. If there is a slight interaction between the zero and span adjustments, repeat step 2. 11 IOI A-~/ k//R E. OJ 0 0 · ~4~' AMALT I' lC,l| ~ flzS CAL/BRAT'OR /'l o ,o ,f'/.. ,j o o o I ~ Ill M - J _ --- ii ii · _1 i I e~ _ - ....... I_11 I I I I III IPIIINTI~ (aN NO. IOQC44-I Ct. II&R/~INT FAINT.OUT _ _. - i I II I II II I ILI I 4N4/. KT'/C,/I/.. CO/V T',~O& $~ //V'C, i I II Ji i i i i · cAi.[, :--' ' '~' ' " I '&P~ovlo BY, D^~, 3 ' I ' 81 . ._ iii i -- · j i · CAt/Z~/T~ for _ J · ii DIqAWINO NUMIIN Ill I. I ZERO £PAN ZEfi O-- SPA N L. --LO ALARM -HI ALAR/q -LO ALARM --HI ALARM ~ TEST --CALIBRATE RESET -CALIBRATE -C H.I-I~ FAiL CH. ZJ SENSOR POWER Figure 3-2. Zero and Span Adjustments PRE-AMF '/' ALARM CH.I F,F~E-AMF +- ALARM C,H. 2 TAC-687 TAC-687 '+/2 V v- {.AL/BRATE TAC-689 SENSOR FO~'ER ~ FA/L TAC-688 NOTE: For a single channel unit, one TAC-687 board is eliminated. TEXAS ANALYTICAL CONTROLS,/NC. ;,-, z-,-az I MODEL 40lB CUSTOMER ADJUSTMENTS 6) If the calibration procedure is completed before the end of the 15 minute delay period, press the calibrate reset switch to reactivate the alarm relays. Calibration of the monitor is recommended once every 90 days, under normal environmental conditions. However, it may be necessary to calibrate The unit more frequently in a more corrosive environment; less frequently in a cleaner environment. It is recommended that each user test for and establish his own calibration cycle based on his application of the unit. Calibration records should be maintained by the user. 3.3 TROUBLESHOOTING The followin~ troubleshooting table is a guide for locating and identifying sources of trouble in the event of system failure. TABLE 3-1. TROUBLESHOOTING - MODEL 40lB AND lO1A H2S SENSOR ASSEMBLY SYMPTOM PROBABLE CAUSE CORRECTIVE ACTION 1. Power LED "oFF". la. Improper input voltage lb. Defective +_15 VDC power supply. lc. Defective LED. la. Check input power connection. lb. Replace. lc. Replace LED. 2. No meter reading. Alarm and meter LED indicators function correctly. 2. Defective meter. 2. Replace meter. 3. Meter reading is adjust- 3a. Defective input ampi i- able to full scale. Meter fier. indicator comes on. Alarm 3b. Defective HIGH and LOW LED indicators do not come alarm LEDs. on at alarm set points. 3a. Replace amplifier. 3b. Replace LEDs. 4. Meter reading is adjust- able to full scale. LOW alarm LED is ON at alarm trip point. HIGH alarm LED is OFF at al arm trip point. 4a. HIGH alarm LED defective. 4b. Defective input ampli- fier. 4a. Replace LED. 4b. Replace amplifier. 5. Meter reading is ad- justable to full scale. LOW alarm LED is OFF at alarm trip point. HIGH alarm LED is ON at alarm trip point. 5a. LOW alarm LED defective. 5b. Defective input ampli- fier. 5a. Replace LED. 5b. Replace amplifier. 6. Meter reading is zero. Alarm LEDs are off. Alarm relays (HIGH and LOW) are activated. 6. Relay contacts are pitted and stuck in the closed position. 6. Replace relay. 14 7. Zero adjustment is highly sensitive. Very slight adjustment results in full scale meter deflection. 8. Controller will not show meter reading when H2S gas applied to sensor. 9. Fail LED "ON". 7. Span adjustment is too high or set for too much gain. 8a. Sensor is defective. 8b. H2S gas sample source is not sufficient. 9a. Defective cable. 9b. Improper connection. 9c. Sensor signal voltage bel ow . 2VDC. 9d. Defective sensor. 7. Check calibration and replace sensor, if necessary. 8a. Replace sensor. 8b. Check calibrator output. 9a. Replace cable. 9b. Check connections. 9c. Adjust trim pot. 9d. Replace sensor. 15 VIII,, ADDITIONAL. INFORI';!ATI. ON HYDROGEN SULFIDE A deadly enemy o~ those peop].e employed :i.n 'Lb(.:.:? pe'!':r'c)l(:::.:um :L~"~dusLr,/, th:Ls gas can paralyze c)r I.:::Lll quicl.::ly.. At. least part o~ the an::.'.w(.:.:.r lies ir; educat, ion in the hazards, symptoms and use prot. ective equ:Lpmen~:. The pr :L nc i pa]. Iqazard 'Lo personr;ei is aspl-,yxiation or po:Lsor",in,.:.:j by inhalat:Lon. Hydrogen Sul'~ide :Ls a calorie:ss, ¥1ammable (..las hay:Lng an o.~:ens:Lve odor and a swee'~ish tas'Le. I'~ is highly 'Loxlc and doub].'/ hazardous because it is heavier than air (specif:[c grav:Lty = iL.. '.Lg). It.~.~ of.J:ensive odor, lil.::e that c:)f an rot. ten egg., has been used as an indicator by many old timers :Ln (.he oil ~ie. lds, but. :Ls not a reliable warn :J. ng o~ ~.]he presence o~ gas i n a dangerous cor~c~ent, r'a'~ i people d:J..~¥er gr'ea'L].y :Ln their abi].ity to detect smells, Where h:Lgh c o n c: e n t. r a t :J. o n s m. r e ~? n c o u n t e r ecl, t h (e o ]..~ a c t (:) r y ri e r" v e s a r e r- a p i d 1 y paralyzed, c:lelud:Lng Lhe sense o~ smell, as a war'ning indicator. A concen'Lrat, ior~ o~ a ~ew hundredth~ o~ one percen'L higher 'Lhan 'Lha'L causilqg :i. rri:Lat:i, on, can cause asl:)hyxiat:J, or] and death - in other words, t: I"~ er e i s a v(.:er' y i] ar r- (~w .... margin between consci ~]u ....... ..~n ~ ..... '=~ ..., _. a n d · ' =~ i ra'Lory alvsi Where high content, rations c:::au.~u resp par , s sponLar",,~ous breathing (Joes not return unless ar'l::j.~ic::Lal respiratior'l :Ls A1Lhough breat, hing is i]ar-a].yzed, ~l"~e hear~ may continue healing ten mlLnut, es a~t. er the attack. [-]_g..g..t_.~.-.~.' Resu]. ts :i. n a 1 most i nstan'Lar~eous asphyx :i. a'L" i or"~, w:i. 'LI'"~ semmi respira'Lory paralysis. Acu~:e poi son :L r~g , or st. rar~gula'L:Lon, may a~ter even a-~ew sec:onds inhmlmtion (]~ high con(:en'Lratiorls a. lqd in pan'Ling r"emp:Lra~ion, pallor, cramps~ paralysis and almos'L immeclia'L:e 1 oss of consol ousness wi th 1 oss o-f spee(zJ'], and i"lo o{]J']er. Wal-'l'] i Fig t.i'],'~'~n cry. Death may ~ol 1 ow wi'Lb extreme rapi [:Ii t.y .~r-om respi r-a'~ory cardiac paralysis. One breath o¥ a sufficient].y high conc::entra'Lion may have this resu].'L. ~L]~.~g.b~.~.: Results in irr:i, tat:i, on, pr:i. ncipa!ly (:)~ 'Lhe eyes, per"s:Lste,",L cough, tightening or" burn:i, ng :Ln the (:::best and sk:Ln irri'~ation .t:c:)].iow~-..,...~ by depress:L on o~ the ten(raiL nervous system. The eye irri'Latior~ ranges :Ln severity ~r-om m:Lld ~.conjunct. iv:L'Li~. swe! ]. :i. ng and bul gi ng o'~ the conjunct :Lve, ph o'Lopl"~ob :L a ( abr-,(::,r ~..~:. L intolerance (::)~ ].igh'[) and 'Lemporary b].indness. I. Victim should be remc)ved to ~resh air immedia'~e-.:'~y by r'~-'- wearing respiratory prot~ec'tive equipment. Protect yours,'.~.?Z[.~ while rescuing. ": I -¢ 't'.'. h e v i c t. i m i ~-' n o t: b r e a t. h :in (..]., b e g i n i m m e d :i. a't: e:. ]. v t: o a p p 1 '..../ ari::i..F i c:i. al respi rat :i. on. :[.{¢ ,_-n. r'e:-]u.sc- i tarot :i ~.--~. ava:[ 1 abl c~,, 1 6:!: anot. her employer..=, get .i.'b and prepare it. ¥or Lt...%e,. . .~= :Lct:Lm warm and com~or~'able 3 'treat .Fc:r shoe:k, l.::~:._-ep v - - 4. Call a doc'bor. In a].l c:a.r~!i, es, v:i. ctims of p(.aisoning shou].,::t at.t. encled by a ph .... ic:Lalq !. E x t r e m e l y t- (3 .'..: :i c. '"' Si::) i-Fic c.]ravi'h.v = I tc~ ,::.. Heavier t-ban ,..-,ir ec ~' Colorles=~ has odor o.F rot~-en .eggs · _~ ~ ..~. -- · 4. Burns wi'b.h a blue ~C~ame and producc--.';s Sulphur g:Lo:.:ide (%02) gas, _. wh:Lcln ±s very ±rr±tat±ng to eyes and ].ungs. The S02 :L~ ,'._'.~.~sc.-~ t:o:.:±c and can cause serious :Lnjury. ~ wit-h ~±r bet:we6..!n 4.3% anld 4.6';/.. P,y ~¢. 1.42S ~Corm~ ,,.~:.,,p'l os± ye mi :.:t. ur~, .. va]. Lt m,:..'a. ~'. H'",_'_'"*= i ,=., a ! m o s't: a s t o ;.: .i. c a s c a r f.-,_ .:]n m o iq o ;.: 4.. d e. 7. B e t w (..-'e. e ~] 5 ;:.~ ri d 6 t. i m E-:,~.-] a s t.. i.] :..'. i c: a ~ c a r b o n m o n o :..'. i d e. 8. Pr(:.~duces irritat, ion 't:o eyes, 't':hroa'l: and resl:):i, rat-.(::~ry t'.ract. 9. T h r e: s In o ]. d I._ i m i 'P. V ,D l Lt (.'.-? ( T L_ V ) ill ~':'..t ;..': i ltl t..t I~] c] ~: (..'e i g h '.h In o u r' '...-'~. e :.: p ,.:)':::. u r r? ~,~ ]i. t h c] t..t ~. p r (3'b e c t: j. v e r' e s p :L r a t o r' y e q u i p m e n t'. - 2 0 P P M. I-F './aLt are -Faced with an H2S pr'obi, em in ,/our opera'(:ic:)r'~s, 'L'.l-',e. ~F o 1 ]. ,::) w i n g s a ¥ e I..':) r a c t.: i c e s a r' e r (.'.-:-., c o mm,:-:.'-: n d e d: 1. B e a b s (21 Ltt. (.? 1 y S L.'.. r e a ! 1 c c, n c: ,,.? r' tn e d a r e ~: a m :L 1 :L a r' w :L t.. I"'~ t'. h e 1'-, a :: a r' ,,:! ~:~.. concerning H.,::~ ar"~d how to avo:ld i 2. A1 t employees shc)ul d know how to operat:e and mai r~ t a:i. n resusc i .I..: - *. or and resp i rat i on equi pmer]'t" .c.4. t.. Sa~e Proc'[:ices (conrad) 3, B e a b 1 e '~ o g i v e a n d d e m c:)n s 't:. r" a t e a r 'L:: .i. ~: :L c i. a 1 r' (.-..-~ ~"..., p" i r" a t i c:) n . 4. Post areas where there :L ~.!-] I:)O:[ ~.:_:,(])r'~l:.')LiS ga,_:; wi 'Eh sLt:L tab ]. e v~ar'n i ~-~(:.:~ s :i. g n s. 5. Be sL~re ali. new employees are 't.".hc)r-oughly scho(i~].ed beC:ore 'i':.h,~.y ar"(...-.-., sent to the .Field -- 'Lomorrow may be t. oo late. 6. Teach a].]. personnel '~'-o avoid gas whenever possible - work c)n the windward side, have a ~resh air mast.:: ava:Liable. 7. Never i et bad judgement gui de you - WEAR RESPIRATORY EQUIPMENT. Never tr"y to hold your breath in order to enter a contaminat, ed atmosphere. 8. In areas o.~ high concer-,tration, a buddy system is recommended. 9. Never enter a rani.::, cellar or other enclosed place where gas can accumulate wi'b. hc:)ut, proper resp:Lr'atory pro'~ective equipment ar"~d a safety belt secured to a li.~e line held by another person out s'i. de. ..... H,::. :.~ d e'L e c:: t o r s b e-F c} · --r..:--~.- .f'i.r'~t w:i.+'l"~ *"" re 1 ~"~ A 1 w a v .s c" h e c 1-:: c:) u ~1" d a n .r:.] c.,? r c.~ u s a r r., ..... ~ .::, a. llc,~..,~:Lr'~g anyone to enter, DO NOT TRY TO DETERMINE THE PRESENCE OF GAS BY ITS ODOR. 11. Wear proper resl:)iratcJr"y equ:Lpment .for the job a'~: hand. Never take a chance w:Lth equ:Ll::)ment which you ar'e unfamiliar. If in doubt, (]o~]st_t]. 'k yot_tr SLtlDeKVJ. sot. 12. C a r r y o u t p r a c t :L c e d r i 1 1 s e v e r y w e e k w :L t h e m e r g e n ("' y a n ,::~ ma:i. ntenance br'eath:Lng eclu:Lpment. Telling or showing a gtc, up how · lzo operate equipment is not enou.q.'h - mal-::e '~hem show you. 13. Max:Lmum care should be t'aken 'kc) prevent the escape o.t: .~ume:s :Ln'Ec~ the air o-F worl-:::Lng pla(:es by ].eal-::s, etc. 14. Colnmunic:at:i.(~ns such as radios and telephones should be provic!ed ~or those people employed where H2S may be present. ....TO.X ............................................. ]] C I TY I-IF L/AR .~ ...FII=:IS ........... [~A~,..::..,,1~.:.-~.~ ('Tal.::er'~ ~r"(3m AF'I. I.--,:F'-49 September Common Name S p e c i ~: i c Chem Gravi t.Y Formula (Air=l) 9 / ~.:)) 1974 - Reissued August. Threshold Hazardous I....ethal I_. :i. m :i 'l: _ .[=-i_/~.)= t. ....!_'_,' g..n.. ~j .r.-.~.p -.P..: ~j'- ,;~. '_~ .:i..'?.ti ", p I:.) m "'5 6,:.]:, i'.':, Hvdrc)gen St.ti.Fide I'q S 1 18 l(') ppm .~: .... (') pl:)m/hr S u ]. 'F u r D i o x :i. d e S 02 :'2.2:1. 5 p p m - 1, ,:} ('.)C., l::> I:::' ,','~ Carbon Mono,'.,' :i de CO C:,. 97 !--',c, I]Pm Zl.C)O i:)pm/l"~r 1, C.)C)C) ppm C a r b o n D i o .'.', i d e C 02 1.5:2: 5 () 00 p p m 5 i/,'. 1 C., % Methane CH4 0 ,. 55 900,:':)0 ppm (]OrT~I:]Lt.=.~'L: i b 1 e .- < ¢*.? '/, ,, .'~ A i::, o v (.:..".- ..¢,. i n a :i r cause death. 2 H a z a r' d o u s.- (::: o n c e n 't: r a t 'i. o n 't: h a .I.': ¢I~a y ._,~' I_et.l-~al - content, ration t. hat will r"ause .... c:leat, l"~ w:i.t.l"~ ,:=hc:)r'l:.--term... .. e ).', p o S Et I'" e. F'roBert:ies o'F Gases The produced gas w:i3.], probably be a mi ;-', tLtre cJ~¢ hyclrogen sul-F:ide and tnethane. c a r b c:] n d :i. o ;.', :id e, 1. Carbc~n Dioxide a. Carbon clioxide (C02), LtSLta].ly considered inert, :is c:ommc)r"~Iv used t.o e,'.,'t, ingu:ish -Fires. It :is heavier t. han air (1.5 L:imes) and it will. content, rate :i.n 1 cannc:,t, breathe air containing mclr'e than 1C>7. CC)2 wi'l:.ho,..,.t. 1 osi ng COl']sci ousness. Air conta:i, n :i. r-,g 5% C02 wi disorientation in a few m:inutes. Continuecl exposur'e t,,:, C:(")2 a~'ber being aY{et:ted wi ]. 1 cause convul si OhS, coma and respiratory ~:ailure. The 't:hreshold 1 :i.m:i.t' c)¥ C02 :i.s 5,0()C:, I::)pm. Short ...... ..~ ~ .., ~.~ .;~ to 50,000 Pl::,m r ,="'.. ,a /. ) i =: r"easc~nabl e "Fh:L .... gas is cc, 3. or]. "~,'",- ar',cl o c:l c) r 1 e .~:~ s a n d c a n b e 't:: o 1 e r a t. ~ d :L n r ~:~ 1 a (:: (3 n c e n t r a t. i c:) n s ,, a. H y (..t r (::) g e n gas,, Ii: l..'31 ...':~ c e s. su:L-F :L cle i s a col or- 1 ess, t.r-ansl::)arer~t, and :¢_..l_..:_~:~.n~.q).:~).[:.:.!~.,:.. :i.s hea ..... :Let thar~ ::air; hence, it may ac:cLtmulat, e ir-~ ',.,,..., Even 'Lbo)ugh Lhe sl'i. gh'l:.e?,'L presence o.~ FI2S :in 'Lhe a:ir s r'; o r ;r, a ]. ]. y c:l o'L e c 'f.: a I.:.~ l e b y :i. 'L s c h a r a c 'lc e r" :i :ss L :i. c "r- ,:~ t:: 'L e n e ~;:j g" e t e c 'b i n g e x ,~'" e s s~. i v e c o r', c: e r", 't: r" a't'.' i o r", s 'L o l::, e a c c u m u ]. a t e d w :i. t I'", ,::::, ,..t 'L w.ar"r~:[ rig. The .Fo,; 1 c:,wi ng 'Lal:::,l e indi c:ates tine:,, po:L SC.~nOLtS r',a'Lur"e C:,-F hyd. r'oger, su]. f i de., COI",IC'EN TRAT I ON G I"'~ 1 H..= o I'-"' F' M 1 ':'.)0 S C 1:"- O. 301 I::. I'" F'.'::. E, ] .~ 10 .65 SaYe ¥or 8 hours with,::)ut resp:Lrator-. Obv;,'3~.',.~:; 100 6.48 K:i.:l. ls sense o4: sme].l in 3 to 15 minutes; may sting eyes and throat. 200 12.96 Kills selqse Q~ smell quicl.::].y~ stings eyes ancl throat. ,JUO 3 ..... 96 Dizziness; breathing %tops in a need prompt art:L~icial respiration. 700 4 5.9 2 Id i'] c o n s c i o Lts q Lti C k 1 y i d e a t h w i 11 r e _ not. rescued promptly. lOC)C) 64.80 Unconscious at once; .loll. owed by death w i t h i n m i n u tL.", ,".=. Sul4:ur Dioxide a. Su].~ur d:Lox:i, de is a colc:)r].ess, transparent, non ...... F].ammabl,m b Sul.Fur di ox i de ¢ ~' ~'. .. . ,=)[],:) is produced during 4-he burning ,:::,-~- ..... .. =Ox. i s . Hgq A].'t:hough ¢, ,~ heav:i, er than air, it will be picl.::ec:! up by tine breeze and carriecl downwind at elevated temper-atu~.-'E.)?,. Since sulEur dioxide is ex'bremely ir-rit, at. ing ~o the e'/es ar'~d mucus membranes o~ the upper r==' r'" _. _ u._,pi at(3ry tract-,, i4- has eXCel]t:Eonal].y good warning powers in 'Ehis respect. The Eollowing table :indicatE..., the toxic nature o-¢ the gas 002 0.01 0.05 0.07 0. 1 CONCENTRAT I ON '/. 802 F'F'P1 0005 . ..:, to 5 .015 :I. 50 ,, 05 500 EFr.:.'ECTS Pungent oclor .- normally a person can de'beet SO2 ir-, this range. Sa-Fe .For 8 hours w:ithout a respirator. Throat irr:itation, coughing, constriction o.F tine chesL, tearing and smarting o¢ the eyes. So ir"ritating it. can only be endured a 4:ew minute~. C a Lt S 8 S S e R ~ e o'F s L(~ 'F O (] 8 t i 0 I'1 ~ e V e n w i t h ~ i r s t b r e a 'L i', C. DO YOU KhlOW? After bre~:t.h:i, ng is stoppec'l .For' 1 M i n u t e The Chances for L.i..Fe are:,' 98 o u t o'F 1 (",1(:) 2 M:Lnute!s 92 out c:)'F 1()() "::._, M :L n u t e s ,,..:. oui: of :L00 4 Mi nutes 50 out of 10"mE) 5 M i n u t e s ..o out of 100 6 M i in u'ls e s !1 out of l('J)()* 7 Mi nutes 8 Minu'lzes 8 out of 10()-.~- 9 Mi nu'tes 2 out o+ :1.()()* 10 Minuttes 1. Ot.t t (.3 4: t. (":,(3. 11 M:Lnuttes 12 Mi nutes 1 out o-F :L,O()O* 1 out. of :L('),000- *Authorities State' Irreparable bra:Ln damage starts at about f:i..Fth m:Lnute. LEARN HOW TO USE LIFE SAVING EQUIPMENT 4.~ SUPPORTING DOCUMENTATION CONSERVATIO June 23, 1987 STEVE COWPER, GOVERNOR 452-1714 Northern Regional Office P.O. Box 1601 Fairbanks, AK 99707-1601 Mr. Cliff Richard Area Manager Amerada Hess 550 West Seventh Avenue # 1400 Anchorage, Alaska 99501 Dear Mr. Richard: Re: General Wastewater Disposal Permit 8740-DB002 Annular Injection Please find enclosed for your use a copy of General Wastewater Disposal Permit Number 8740, DB002 for the injection of drilling fluids down the annulus of wells drilled on the North Slope, If you have any questions you may contact me at the above telephone number. Any person who disagrees with this decision may appeal by requesting an adjudicatory hearing, using the proc.edures contained in 18 AAC 15.200-310. Hearing requests must be delivered to the Commissioner of the Department of Environmental Conservation, 3200 Hospital drive, P. O. Box O, Juneau, Alaska 99811, within 30 days of receipt of this letter. If a hearing is not requested within 30 days, the right to appeal is waived and the decision becomes final. Enclosure BRF:tss cc: A. Ott, ADFG/Fairbanks T. Booth, USFWS/Fairbanks J. Brossia, ADNR/Fairbanks W. Matumeak, NSB/Barrow B. Lamoreaux, ADEC/Anchorage C. Chatterton, AOGCC/Fairbanks A. Kyle, ADEC/Juneau L. Dietrick, ADEC/Fairbanks 900.45.010 Sincerely, Bradley R. Fristoe Environmental Engineer STATE OF ALASKA DEP~-~,FMENT OF ENVIRONMENTAL "~ NSERVATION P. O. BOX 0 JUNEAU. ALASKA 99811-1800 GENERAL WASTEWATER DISPOSAL PERMIT Permit No. 8740-DB002 This general wastewater disposal permit is issued for the disposal of wastewater by injection through oil and gas wells within the Department of Environmental Conservation's Northern Region, north of 69° latitude. Fluids disposed through wells for which the primary purpose is waste injection are not included under this permit. This permit applies to the disposal of fluids produced from the drilling, servicing, or testing of oil and gas exploratory, development, service and stratigraphic test wells, including, but not limited to, drilling fluids, rig washwaters, completion fluids, formation fluids, reserve pit fluids, and domestic wastewaters. The disposal is to be into the lands of the state below the permafrost zone. This permit is subject to the conditions and stipulations contained in Appendices A and B, which are incorporated herein by reference. The department will require a person to obtain an individual permit when the disposal does not meet the conditions of the general 'permit, contributes to pollution, or causes an adverse impact on public health or water quality, or a change occurs in the availability of technology or practices for the control or abatement of pollutants contained in the disposal. This permit is issued under provisions of Alaska Statute 46.03, the Alaska Administrative Code, as amended or revised, and other applicable state laws and regulations, including standards of the Alaska Coastal Management Program under 6 AAC 80. This permit is effective upon issuance and expires A_t!ril 30, 1992. It may be terminated, modified, or renewed in accordance with AS 46.03.120. Regional Environmental Supervisor ~erm~ o ~,+u- u ~uu,' age 2 of 6 APPENDIX A - SPECIFIC PERMIT CONDITIONS I. ~NOTIC£ OF DISPOSAL A, Applicants wanting to conduct disposal activities under this permit must notify the department's Northern Regional Office in writing at least two weeks prior to each disposal. Shorter notice and verbal notification followed by written confirmation may be used for emergency situations where dewatering is required to prevent washout of pit dikes. B, Notifications submitted under I.A. must include the following information: 1. Well designation or name, and description of the well with a map or plat of the well location. 2, A list of materials to be injected, des'cription of the materials, estimated volumes of each material, and sources of all materials to be injected, 3. The total estimated volume of material to be disposed. 4*. A description of the zone that the wastewater will be entering including the top and bottom depths, the geological make-up of the zone, the geological make-up above and below the zone, permeability of the zone, operating pressure of the zone, and salinity of the ambient water within the zone. 5. The depth at which injection will occur. 6. Beginning and ending dates the disposal will occur. , A schematic of the well and casing layout to a point 100 feet below the bottom of the injection zone. e The ~method to be used to seal the injection zone when disposals are finished. 9. Anticipated time by when the injection zone will be sealed. For wells where this information will not be available prior to disposal, as in an exploration well, ~the information is to be reported in the final report required in Section III. t~.~ age 3 of 6 C. Appl,cants must have written approval from the Regional Supervisor of the Northern Regional Office before conducting particular disposal activities under this permit. Verbal authorization, followed by written confirmation, may be given for emergency situations where dewatering is required to prevent washout of pit dikes. D. The department will, in its discretion, attach terms and conditions appropriate for specific disposal activities. II. EFFLUENT LIMITATIONS A. This permit does not authorize the injection of hazardous waste as defined in Title 40, Part 261, of the Code of Federal Regulations. Be Discharges authorized by this permit are limited to fluids produced from the drilling, servicing, or testing of oil and gas exploration, development, service and stratigraphic wells, including, but not limited to, drilling fluids, rig washwaters, completion fluids, formation fluids, reserve pit fluids, and domestic wastewater, unless otherwise approved in writing. C. The well shall comply with 20 AAC 25 of the Oil and Gas Conservation Commission Regulations, D. The discharge is to occur at a minimum total vertical depth of 1,O00 feet and must occur below the permafrost zone. E. Discharges will not be allowed into zones containing water with less than 3,000 milligrams per liter total dissolved solids. F. Wastes from'other parties will not be allowed without prior written approval of the Regional Environmental Supervisor of the Northern Regional Office. G. Any flow of liquids originating from the activity to the surface of the g.round is prohibited. H. The discharge shall not cause a violation of the State Water Quality Standards (18 AAC 70) to any fresh water aquifers containing less than 3,000 milligrams per liter total dissolved solids and surface waters. I. The disposal shall not cause adverse effect on aquatic or terrestrial plant or animal life, their reproduction, or habitat. III. RE CORDS .,,4D REPORTING age The permittee shall maintain a log at the injection site containing the well location; well designation; date, type, and volume of materials injected; method of injection; and depth of the injection zone. The log shall also note any unusual complications or significant maintenance activities and any change of information provided in the notice of disposal. A summary of logged information shall be prepared at the end of the disposal and a signed copy shall be submitted to the department within 30 days of the end of the disposal period stated in the written approval from the Regional Supervisor or upon approval from the department, quarterly reports may be substituted. If permitted wells are not used for disposal by the end of the disposal period stated in the written approval from the Regional Supervisor, a report stating that the well was not used for disposal shall be submitted to the department within 30 days of that date. Reports shall be submitted to'. State of Alaska Department of Environmental Conservation P. O, Box 1601 Fairbanks, Alaska 99707-1601 (907) 452-1714 IV. MANAGEMENT REQ_UIREMENTS A, Change in Discharge All discharges authorized herein shall be consistent with the terms and conditions of this permit. The discharge of any pollutant or toxic material more frequently than, or at a concentration or limit not authorized, shall constitute noncompliance with the permit. Any anticipated facility expansions, flow increase, or process modifications which will result in new, different or increased discharges of pollutants must be reported by submission of a new notice of disposal to the department at the Northern Regional Office, P. O. Box 1601, Fairbanks, Alaska 99707-1601, at least two weeks before the implementation of such changes. Physical changes may also be subject to plan review by the department. B, Toxic Pollutants If a toxic pollutant, including oil, grease, or solvents concentration standard is established in accordance with 18 AAC 70 for a pollutant present in this disposal, and such standard is more stringent than the limitation in this permit, this permit is considered to be modified in accordance with the toxic pollutant concentration standard. C, Nonc. 21lance Notification ~ ~ge 5 of 6 If for any reason the permittee does not comply with, or will be'unable to comply with, and effluent limitation specified in this permit or Water Quality Standards under 18 AAC 70, the permittee shall immediately stop discharging and report the noncompliance to the Northern Regional Office within 2~, hours of becoming aware of such conditions by telephone or telegraph, or in the absence of both, by mail. 2. A written follow-up report shall be sent to the Northern Regional Office within seven days of the reported event, The written report shall contain, but not be limited to: a. Times and dates on which the event occurred, b, A detailed description of the event, including quantities and types of material involved. c, Details of any damage to the receiving environment. d. Details of actions taken or to be taken to correct the causes of the event, e. Details of actions taken or to be taken to correct any damage resulting from the event, V. EXCLUSION FROM THE GENERAL PERMIT Any permittee authorized by this permit may request to be excluded from the coverage of this general permit by applying for an individual permit. The owner or operator shall submit an application together with the reason supporting the request to the Northern Regional Office no later than 60 days after the effective date of the permit. VI. INDIVIDUAL PERMIT When an individual permit is issued to a permittee otherwise subject to this general permit, the applicability of this permit to that owner or operator is automatically terminated on the effective date of the individual permit. VII. TERMINATION 'OF ACTIVITIES UNDER A GENERAL PERMIT The department will, in its discretion, require a person with a general permit to obtain an individual permit when situations including, but not limited to, the following occur: A, The disposal does not meet the conditions of the general permit. B, The disposal contributed to pollution or caused an adverse impact on public health or water quality. C. A change occurs in the availability of technology or practices for the control or abatement of pollution contained in the disposal. ermit 8740- DBO02 ~age 6 of 6 APPENDIX B - GENERAL PERMIT CONDITIONS I. ACCESS AND INSPECTION The department's representative shall be allowed access to the permittee's facilities to conduct scheduled or unscheduled inspections or tests to determine compliance with-this permit, state laws, and regulations. ~ II. INFORMATION ACCESS Except for information relating to confidential processes or methods of manufacture, all records and reports submitted in accordance with the terms of this permit shall be available for public inspection at the Northern Regional Office of the Alaska Department of Environmental Conservation, lOO1 Noble Street, Suite 350, Fairbanks, Alaska 99701. III. CIVIL AND CRIMINAL LIABILITY Nothing in this permit shall be construed to relieve the permittee from civil or criminal penalties for noncompliance, whether or not such noncompliance is due to factors beyond his control, including,. but not limited to, accidents, equipment breakdowns, or labor disputes. IV. AVAILABILITY The permittee shall post or maintain a copy of this permit available to the public at the disposal facility. V. ADVERSE IMPACT The permittee shall take all neCessary means to minimize any adverse impact to the receiving waters or lands resulting from noncompliance with any limitation specified in this permit, including any additional monitoring needed to determine the nature and 'impact of the noncomplying activity, The permittee shall clean up and restore all areas adversely impacted by the noncompliance. VI. CULTURAL OR PALEONTOLOGICAL RESOURCES Should cultural or paleontological resources be discovered as a result of this activity, work which would disturb such resources is to be stopped, and the Office of History and Archaeology, Division of Parks and Outdoor Recreation, Department of Natural Resources, is to be notified immediately {907-276-2653}. SCHEMATIC DIAGRAM OF THE DIVERTER SYSTEM OF THE PARKER RIG 217 CIDS 21¼" 2000 PSI ~P Ak%ruTAR DIVERTER 10" D~ L/lqES 10" 300 PSI WP ~ICALLY OPERATED D~ BALL VALVES 10" DIVERTER LINES 10" 300 PSI WP HYI]RAULICA_T.Ly OPERATED D~ BALL VALVES DRIVE PIPE DIVERTER SYSTEM COMPONENTS 1. One (1) - 21 1/4" 2000 psi wp annular diverter with spare element. 2. One (1) - 21 1/4" 2000 psi wp drilling spool with two 10" outlets. 3. Two (2) - 10" 300 psi wp hydraulically operated diverter ball values. 4. Two (2) - 10" diverter lines. D 1-v~£~ OPERATION 111~- CLOSING UNE r , PILOT UNE TO OPERATORS &CCUMULATOR 3.WAY VdIJ,.Vl ~ ~e hy~a~ic l~s ~e ~s~ll~ ~ a ~~ ~t ~ hy~a~ic clos~g press~e fr~ ~e a~~a~r is ~ppli~ to ~e ~ul~ BOP it ~li~ ~~g hy~aulic press~e to ~e ~11 ~v~. ~e ~l~r Valve c~ ~v~ ~e fl~ ~ ~ r~~ d~tion. STERN IO"DIVERTER /LINE DRILLING WELL STAR BOAR D PORT HELIDECK IO" DIVERTER /LINE BOW Through Hull Routing of 10" Diverter Lines SCHEMATIC DIAGRAM OF THE BLOWOUT PREVENTER STACK FOR PARKER RIG 217 CIDS ~ R,4M SPOOl.. ]3-5/8', 10,000 psi wp BOPE Comppnents 1. One single 13-5/8" X 10,000 psi type U Cameron blowout preventer with H2S trim. 2. One double 13-5/8" X 10,000 psi type U Cameron blowout preventer with H2S trim. 3. One 13-5/8" X 5,000 psi Cameron Type "D" annular preventer with companion flange to bell nipple. 4. Blowout preventers are certified for H2S. 5. Blowout preventer handling system. 6. Drilling spool - 13-5/8" X 10,000 psi WP. 7. Drill pipe test joints. 8. Ram blocks - 3 sets 3-1/2" X 10,000 psi 3 sets 5" X ]0,000 psi 2 sets blinds 9. Annular Element: One spare. 10. BOP Choke and Kill Line System" 10,000 psi wp. LINE I I .4M ~ ASIg-aO Ge.. CAO~£ PIAMF~D iMTEO Jq.P.-IO00 P. II.~ WP 1J~ TESt 4~ &PI &A FtANGE P.~I~. (~7 ,fEET .. 4' SCH. ~ P.$.L~ V~LI~ W£L~D #ore ,,,-~. ~ W. qflqER tgWgN RS.I.G. TEST t~T'L ~I'M d1519 41~0 I.fO0o A~rt9 ~-~0 GR. 4,tJO k~LL GR. 4/3O I.. ~ t.G. t,l. tf I ' [ I I ti ! I IAI ~e~ L ~ r~ :; , ' ' . . b,,., ........ I~ I,.~.l ._l~ I · I ~:~CJ< LAYC~IT_ 47~ L i-l~l I11 III III ill 7(~ W. (&'-4 ~~-~:1 I /:! -- la~l , ~ ~-+-1~----:- I {"l I I I ~::.::.::-:~-I.._-.:~._.-:__-;: I o,~_,,c. I i IL_I__ ' I bi-El I :,_, ~__--.-y~' l=',-l-i~'L:.-~i ~i :m: I I i__l I I I ~'~'----I~.:--'i- i'';'~." . l, BOP Equipment: 1. Anticipated Surface Pressures: Size of Casing Depth Anticipated Surface Pressure 13 3/8" 3000' 1500 psi 9 5/8" 10700' 3904 psi 7" 11350 3904 psi Criteria used to determine this pressure: Lesse= of fracture gradient at the casing shoe minus 0.~5 gas gradient or maxium anticipated formation pressure minus 0.i5 gas ~ gradient to the surface. MUD PROGRAM Straight Well SUGGESTED PROPERTIES: (Spud Mud) - 13-3/8" Casing TVD Densit~ PV YP Gels. FL , Surface 8.8-9.4 Funnel 40-60 to' 200 to 3,000 ' 300 sec/qt. % % Oil Solids 40-60 15-25 0 6-8 pH Spud Mud 9-10 Spud with 300 sec. viscositY spud mud. Pre-treat with Soda Ash to remove excess calcium. Build initial viscosity with bentonite and extender (Bentonite/Bentonite Extender - 5/1). Run shakers, desander and desilter to keep abrasive solids at an acceptable level. Below the gravel interval. Reduce viscosity to 100 sec/qt, prior to cementing. (Exact viscosity requirements will be a function of the amount of gravel present). Suggested Properties: (Low Solids Nondispersed Mud) - 12-1/4" Hole % % TVD Density P?... Y~... Gels. FL _O_il.. Solids pH 3,000 ' 8.8-9.5 6-12 to 9,700! 5-8 2-10 6-8 0 6-8 9-10 Drill out with a low solids nondispersed system. Dump and clean the pits and treat the make-up with Soda Ash. Use the spud mud in the casing as the base for the new system. Discard severely contaminated mud when drilling the cement at the 13-3/8" shoe. Drill ahead keeping the pH moderate (9.0-9.5) with Caustic Soda. Light treatments with Anionic Polymer (cellulose polymer) will provide useful stabilization through this interval. The Anionic Polymer additions will reduce API fluid loss, as well as, provide effective polymer coating. Drilling soap and Wall-Nut hulls may also be useful by reducing balling problems. The primary objective for this interval is to maintain a "clean low solids system which will be consistent with the recommendations, as presented later in this program, for drilling the potentially troublesome Kingak Shale at 9,700'. The success of these efforts will be directly related to the effectiveness of the solids control system available for the test. Being to increase mud weight below 8,000' TVD as necessary to control potential shale problems. Increase mud weihgt with barite, and do not let drill solids build up. Do not weight up prematurely. The Kingak shale that will be encountered on this test (9,700') is a pressured, thistle shale that is present over much of the North Slope area, both onshore and offshore. It has created drilling problems on most wells in the area, resulting in delays in drilling and quite often stuck drilling strings. The best approach to successfully drilling this shale must be a combination of mud weight, minimal additions of dispersants, and sound drilling practices. Mud weights to 11.5 lb/gallon may be needed to overcome pore pressures. Assuming a fresh water mud system will be used, high yield points are recommended to insure good hole cleaning. A polymer such as Anionic Polymer will not only provide these high yield points, but would reduce filtration rates to the 5±cc range. High gel strengths may also be needed to prevent bridging of sloughing shale during trips. Experience has shown that once the kelly is picked up to ream a bridge, is often necessary to rean from that point on to bottom. The addition of Polymer Deflocculant (to 3 ppb) and Dispersant (to 2 ppb) should be used on an as needed basis to control the excessive rheology which may tend to develop. The use of lignites and lignosultonates should not be initiated until other techniques have proven unsuccessful. TVD Density Gels FL 9'~700' 11.5 10~15 6-10 2-10 2-4 10,700' % % Oil. Solids pH 0 9-12 9-10 When in the Kingak shale, annular velocities should be maintained below turbulent flow around drill collars. Prior to tripping for a new bit, bottoms up should be circulated. On tripping into the hole, circulation should not be initiated across the Kingak unless a bridge is encountered. If an iron roughneck is not available on the rig, it is recommended that the drill pipe be chained out when pipe is pulled through the Kingak. All efforts should be made to avoid mechanically disturbing the shale. Time appears to be another key element in successfully drilling of the Kingak. It is suggested that the interval is drilled, logged and cased as quickly as possible to minimize exposure and reduce potential problems. To summarize these recommendations for the Kingak, the following points are noted: 1. Use Polymer Deflocculant and Dispersant on an as needed basis to avoid the requirements for standard Lignite and Lignosultonate treatments. . Mud weights up to 11.5 ppg may be required. · Reduce API fluid loss to 2 - 4cc with Anionic Polymer and Lignite/Resin Blend. · 5· Maintain a moderate pH with Caustic Soda 9.5 - 10.0 range. Avoid turbulent flow in the annulus. ~ Maintain higher than normal yield points and get structures to provide adequate hole cleaning and suspension. ~ Avoid excessive surge and swab pressures while tripping through the shale. · Chain out on trips through the interval. · Minimize exposure. Case off as quickly as possible. 10. Asphalt type additives (Soltex) may be useful. Should torque or drag become excessive, treat with medium nut hulls and screen out at shaker. If torque or drag continues, treat system with 2 - 4 ppb Lubricant. TVD Density PV YP 1--~,700' 9.5-10.5 i0-20 8-30 to 9-5/8" 8- 20 Casing Pt. 11,350' % Gels FL Solids pH 4-18 ~-'6 1/4 15% 9.5-10.0 8-12 3- 10% Below 9-5/8" casing properties as above. lightly disperse system and maintain RESUME Name: Gary J. Monroe Age: 38 Date of Hire: 1/2/73 Education: BA University of North Dakota Res i dence: Anchorage, Alaska Alaska Experience: Areas Worked: 13 years Prudhoe Bay Unit ARCO Rowan 34 Gulf of Alaska - Exxon Co. U.S.A. North Slope Exploration Phillips Staines River Husky Oil NPRA ' Gulf Oil Pt. McIntire West Sak Gulf Cross Island Gulf St. George Basin Amerada Hess - Northstar #1 Cook Inlet Onshore and Offshore Union Oil Co. of California Marathon Oil Company Monroe worked 3~ years for ARCO on Rowan 34 in the Prudhoe Bay Unit. He worked for Husky four years on NPRA at various wildcat wells. He has worked some early Wes~ Sak exploration wells and in the Staines River area for Phillips. Monroe worked three wells in the Gulf of Alaska for Exxon. He also has worked several Beaufort Sea wells including Northstar No. i for Amerada Hess. Professional Training: Baroid Phase I through Phase IV training. Well Control School. Drilling Practices School (Preston Moore). RESUME Name: William L. Rintoul Age: 38 Date of Hire: 12/1/74 Education: BA University of NRrth Dakota Residence: Anchorage, Alaska Alaska. Experience: 13 years Areas Worked: Prudhoe Bay Unit ARCO Rowan 34 Sohio Nabors 22E Kuparuk River Unit ARCO Rowan 34 ' West Sak NPRA Husky Exploration Wells Cook Inlet - Onshore and Offshore Rintoul has worked approximately five years in the prudhoe Bay Unit for ARCO and Sohio. He has worked two years in the Kuparuk area for ARCO. He worked four years at NPRA for Husky on various exploration wells. He has extensive work at the Prudhoe Bay Unit on completion/workover operations. Professional Training: Baroid Phase I through Phase IV training. Baroid Applied Drilling Technology Course. Well Control School. RESUME Name: Age~ Date of Hire: Education: Residence: Alaska Experience: Areas Worked: William K. Wallace 44 7/1/85 BA Pan American ,University Eagle River, Alaska 18 years (16 years with Imco services) · North Slope ARCO - Prudhoe Bay Unit ARCO - Kuparuk River Unit Forest Oil - Lupine Unit Amerada Hess - Northstar ~1 · Texaco - Gulf of Alaska ARCO - Cook Inlet Union Oil of CalifOrnia - Cook Inlet Marathon Oil - Cook Inlet Wallace has worked all areas of Alaska and has extensive experience on the North Slope and Beaufort Sea areas. {Senior Technical Services Engiener for Imco Services). Professional Training: Imco Basic and Advanced Dri 11 ing Fluids School. Imco Drilling Engineering Courses. u[- ~ ! r~ r_.~w/ ppq TVD 8.0 9/'~'',, iO.O I1.0 12.0 13.0 14.0 150 16.0 0.416 0.468 0.520 0.572 0.624 0.676 0.728 0.780 0.852 GRADIENT psi/ft. AMERADA HESS CORPORATION NORTHSTAR NO. 3 GENERALIZED ESTIMATED PORE PRESSURE / MUD WEIGHT FRACTURE GRADIENT I000 20"(~) ) 300' BML, Nipple Up Diverter 2000 3000 LOGS, RUN t3 :~8" CASING 4000 5 000 ~: 6 000 c3 70 O0 8OO0 9OOO I0,000 ii ,000 12,000 LOGS LOGS, RUN 95/8" CASING 5 [0 15 20 25 LOGS, RUN7,, LiNER 30 35 40 45 TI ME / DAYS TESTING 50 55 60 Estimated Time vs. Depth Chart Amerada Hess Corporation Northstar No. 3 9'.0 SHALLOW GEOHAZARD REPORTS The geohazard assessment of the Northstar No. 3 location is presented in the following three reports: Investigation of Rock Habitats and Sub-Seabed Conditions, Beaufort Sea, Alaska. Harding-Lawson Associates, Anchorage, Alaska. Dated December 10, 1980. This report describes both geophysical and geologic observations in the area of lease blocks BF46 and BF47. High resolution seismic reflection records from this study indicate only one small area of signal attenuation indicative of acoustically turbid sediments having a high compressibility due to the presence of interstitial gas bubbles. This area is located over 3 miles to the south-southeast of the proposed well location. No signal attentuation indicative of hydrocarbon presence was observed in the area of the proposed location. Seismicity of the area is very low. 2. Geotechnical Investigation Site B, Northstar - Seal Area, Beaufort Sea, Alaska. EBA Engineering Inc., Edmonton, .Alberta, Canad~a. J_u. ly 1987. This report is presented in a stand alone volume which accompanies this application. The report concludes that the Northstar No. 3 location (Site B) is geotechnically suitable for the deployment of a bottom founded drilling structure. 3. Results of the CIDS Location Survey, Beaufort Sea, Alaska. NORTEC, A Division of ERT, Anchorage, Alaska. August, 1987. This report presents the findings of a detailed bathymetric and side scan sonar survey run in the immediate area of the proposed CIDS footprint. No significant ice scour or other sea floor anomalies were identified during this survey. ' HARDING-LAWSON ASSOCIATES INVESTIGATION OF ROCK HABITATS AND SUB-SEABED CONDITIONS BEAUFORT SEA, ALASKA HLA 3ob No. 9612,012.08 A Report Prepared for Amerada Hess Corporation by Lawrence 3. Toimil; Senior Geophysicist Harding-Lawson Associates Anchorage, Alaska in cooperation with Biological Consultants Kinnetic Laboratories, Inc. Santa Cruz, California December 10, 1980 y--*-~, H i~-~q~lG- LAWSON ASSOCIATES TABLE OF CONTENTS LIST OF TABLES LIST OF FIGURES LIST OF PLATES ACK N OWLEDG EME N TS I SUMMARY II INTRODUCTION A. Background B. Purpose C. Scope of Work III REGIONAL GEOLOGY AND BIOLOGY A. Holocene Stratigraphy B. Pleistocene Stratigraphy C. Resource Materials D. Ice-Related Geologic Processes E. Offshore Permafrost F. Regional Biology IV CALIBRATION A. Approach B. Procedures C. Findings D. Recognition of Rock Habitats V SURVEY A. Coverage B. Geophysical Procedures C. Direct Seabed'Observation Procedures D. Data Reduction VI RESULTS A. Bathymetry B. Rock Cover C. Direct Seabed Observations D. Surficial Bottom Features E. Thickness of Marine Sediments F. Acoustic Anomalies iv vi vii 7 10 11 13 16 18 18 18 23 28 29 29 29 31 32 V SURVEY HARDING-LAWSON ASSOCIATes A. Coverag. e A total of 219 miles (37 miles in Tract69 and 162 miles in Tracts 46 and ~7) of geophysical tracklines and 7 trackline miles of direct seabed observations were covered during survey operations. Geophysical tracklines are shown on Plates 2 and 10 and the direct observation lines on Plate 3. For the geophysical survey, a line spacing of 200 rr, was maintained for lines oriented approximately northeast-southwest (070°T -230°T). Tie lines were run in northwest-southeast (3~0°T - 160°T) with a spacing of 1000 m. Pack ice and shoals precluded the collection of data in localized portions of Tract 46. Breaks in lines due to ice and inclement weather resulted in nonconsecutive shot point numbers along some tracklines. All four geophysical systems were operated concurrently on the survey tracklines shown on Plates 2 and 10. B. Geophysical Procedures 1. General The selection of operational settings used for the geophysical systems during the survey were established from the results of the calibration tests. Transducer depths, survey speeds, filter settings and gain levels were fixed at the values established during the calibration tests. _~ Navigation information was obtained by International Technology Limited (]TECH) using a Motorola Mini-Ranger llI system, which included a data processing unit, a digital recorder, a real time plotter, and a steering indicator. The vessel's position was continually tracked on a real time plotter along predetermined tracklines. HARDING-LAWSON ASSOCIATES Navigation fixes (shot points) were taken at the start and end of each transect and at 200m intervals. The navigation data processor was interfaced with the geophysical recorders to ensure simultaneous annotation of ali systems. 2. Water Depth Measurement and Seabed Profiles A Raytheon 200 kHz ;~athometer was used to coJ]ect bathymetric data and seabed profiles. Two Sea Data tide gauges provided local tidal information. The gauges were located on Nar~'ha] island for the survey at Tract 69 and a portion of the Tract 46 and 47 survey. The gauges were then moved to Long lsIand prior to finishing the survey at Tracts 46 and 47. Field maps of the percent rock cover, based o~ correlations established for the 200 kHz fathometer during calibration tests, were used to determine whjc:h portions of survey tracklines would be most suitable for the direct observation survey. Areas in which the geophysical data were inconclusive (i.e., the percent rock cover was not clearly defined) were also chosen for further investigation. 3. Side-Scan Sonar A Klein ~00kHz sea floor mapping side-scan sonar system (K-Map System) provided sonographs o:~ the seabed. A recorder range scale of 100 meters per channel was used. 4. Subbottom Profiles system. width. High resolution subbottom data were collected using, a Raytheon 7.0 kHz The transceiver was operated with a -12dB attenuation and a 0.6ms pulse HARDING-LAWSON ASSOCIATES A Van Reenan Mono-Pulser subbottom profiling system was used to obtain profiles of seabed substructures. Operating with a filtered band pass of between 400 and 1800 Hz, the system is capable of penetrating the sea floor to a depth of 50 n~eters with a resolution of about I meter. A power output of 125 joules was used together with a firing rate of 2/5 second and a recorder sweep rate of 1/5 second. C. Direct Seabed Observation Procedures Two methods of direct observation were used to study the geological and biological characteristics of the seabed in the survey area. These methods were 1) towing a diver on a sled, and 2) towing an underwater television camera on a wheeled vehicle. Each method is described in the following sections. 1. Diver 51ed A diver on the sled was towed above the seabed at a speed of approximately 1.5 to 2 knots (see Appendix B for a detailed description of the diver sled). Diver observations of the substrate and organisms were transmitted to the boat via a hard wire communication system and recorded. Navigation shot point numbers were recorded at 50 m intervals. Since the sled was towed about 20 m behind the survey vessel, observations correspond to an area approximately 20 m behind the shot point. The diver on the sled generally scanned the seabed on either side of the sled to a distance of I to 2m, depending on visibility. Observations of the predominant substrate type as well as estimates of the abundance of prominent epibenthic macrobiota (macroscopic species living upon the seabed) were transmitted to the surface tape recorder. Muddy sand was differentiated from silty mud by the presence of sand ripples or waves, and rock habitats were defined as areas of numerous cobbles and boulders. The presence of topographic variations such as ice gouges or clay deposits was also reported. ARDING-LAWSON ASSOCIATES 2. Underwater Television The underwater television (UTV) camera was attached to a wheeled vehicle which was towed behind the survey vessel. The wheels allowed the vehicle to roil smoothly over boulders and ice gouges, while trim tabs kept it firmly on the bottom as it was towed (see AppendixB for a detailed description of the UTV vehicle). Towing speed was about one knot. Video records were transmitted from the camera to a consoJe/n~onitor on the vessel via an umbilical and recorded on broadcast-quality 3/~-in. tape. The date, location, and shot points 50 m apart were recorded on each tape through a microphone connected to the video recorder. D. Data Reduction. Geophysical data collected during this investigation were returned to the HLA office in Novato, California for interpretation. The results were plotted at a scale of I in. = 2000 ft. on maps which include bathymetry, percent rock cover, ice gouges and strudel scour areas, sand wave and stiff clay areas, clay isopach and acoustic anomalies. I. ~'ater Depth ~'ater depths were measured to the nearest 0.1 foot directly from the fathograms 'at each shot point. A tidal correction was then added to each depth measurement. A tidal curve was constructed from tidal data collected at Narwhal Island for the period August 7-2l, -lgg0, and at Long Island from August 24 to September 10, 19g0. Because of the lack of an accurate Mean Sea Level Datum for the area, a local Mean Sea Level for the study period was calculated from the tidal curves. The mean tidal height for each tidal cycle was determined. These measurements were avera~zed at each tidal station over the survey period, and the mean tidal height for the study period dARDINQ-LAWsoN ASSOCIATES was then used as the local Mean Sea Level Datum for each tidal station. Anadiustment between the two datums was determined by rerunning; a bathymetric profile after the second tidal station was established. The corrected water depths at the shot points were plotted at a horizontal scale of ! inch = 1340 feet and contoured at J-:loot intervals. The resulting bathymetric map was photographically reduced to a scale of ! inch = 2000 feet. 2. Rock Cover Percent rock cover on the sea bottom was determined based on correlations between the geophysical data and direct measurements of percent rock cover established during the calibration phase of the investiCation, as described earlier. Three major rock cover percenta§e categories were readily recognized from the calibration tests: less than 10%~ l0 to 25%~ and greater than 25%. The latter category is important because it corresponds to the rock cover at OCSEAP DS-Il. Spike-like traces were counted on the fathograms and adjusted according to procedures established during the calibration tests. The resulting values were placed in one of the three rock cover percentage categories and plotted over the study area. 3. Direct Seabed Observations a. Diver Sled The diver sled tapes were transcribed at the KI laboratory in Santa Cruz and the observed seabed characteristics were listed at lO0-meter intervals, i.e., every two shot points. These data were further reduced by grouping biota.-according to substrate type and shot point. b. Underwater Television Analysis of the video records required several steps. Biologists viewed each entire tape and recorded essentially the same type of data as noted by divers on the sled. Numbers of individuals of abundant species were tallied for muddy bottoms. · · HARDING-LAWSON A$$OC;IATES Stills of lm sampl~ areas were exan~ined at random tape-counter numbers for each rock habitat area. The percent cover of rock habitat (boulders and cobbles) and organisms was visually estimated from each still. ,The number of rarely seen species was qualitatively assessed. By examining the percentage of rock habitat cover determined over l m areas fron~ each of five calibration dive sites, it was determined that 5 percent was the minimum coverage on video records required to adequately sample an area. The running mean values shown on Figures 6 through ]0 establish that determinations of rock cover based on .5 percent coverage do not significantly differ from determinations based on 100 percent coverage. Ice Gouges and 5tiff Clay The sonographs were compared with the fathograms and the 7.0 kHz profiles to aid in the recognition of bottom features and the distribution of clay outcrops. A clay bottom was characterized by blocky or highly gouged areas, which were recognized from moderate to high contrast (shadows on the sonographs). The ice gouges appeared on the sonographs as dark lineations with light areas on one or both sides. The light areas were caused by an oblique view of a low ridge or berm formed by the displacement of bottom materials away from a central low area. 5. Sand ~;;aves and 5truclel Scour Sand waves were recognized by alternating, closely spaced dark and light areas of a characteristic rippling shape. The sand wave areas are largely irregular but occasionally exhibit a crescent form. Strudel scour areas are characterized by a roughly circular or oblate depression. A depressed central area, observed as a light area on the records, being partially or completely surrounded by a ridge or berm formed by the displacement of bottom materialS, was typical of most scours observed. ~-"~', ~'~' HAIIDING-LAW$ON ASSOCIATES VI RESULTS A. Bathymetr)' I. Tract 69 Bathymetric data for Tract 69 contou.red at l-foot intervals are presented on Plate 3. ~ater depths range bet~,een l0 and 26 feet. The contours depict smooth and relatively flat slope gradients. In the eastern corner of the tract, the character of the seabed is broken by an abrupt rise from depths of 22 feet. The rise marks the southern flank of the Reindeer-Cross Island-Dinkum Sands Ridge, ~vhich is composed of southward migrating sands and gravels. These materials appear to lie at their angle of repose along the southern ridge flank. 2. Tract's 46 and 47 Bathymetric data for Tracts 46 and 47 contoured at a l-foot interval are presented on Plate I I. Water depths are bet~,een l~; and 4~ feet and show a general increase in complexity ~vith a decrease in water depth. The contour complexity near shore of Long Island 'is probably caused by ice processes and the littoral drift of migrating sands. B. Rock Cover Rock cover percentage, including cobbles and boulders combined for Tract 69, is presented on Plate 4, Rock Cover Map. Two small localized areas having rock cover of bet~veen 10 and 2~ percent are present in the tract. There are no rock cover areas comparable to that at OCSEAP DS-II (greater than 2J percent). Previous studies have not defined significant biological communities or habitats within Tracts 46 and 47. HARDING-LAWSON ASSOCIATES C. Direct Seabed Observations Direct observation survey track]ines ~'ere superimposed over the rock cover distribution presented on Plate~ and are shown on PlateS. Botton~ types and biota seen · along the direct observation tracklines within Tract 69 have been keyed to navigation shot points and are presented for comparison in AppendixES. Basically only muddy bottom was recorded by divers on the sled. Observations alonR the one run correlate with the geophysical estimates. No rock habitats were observed in an), o:[ the video records for Tract 69. Areas of occasional cobbies were scattered along ali three UTV lines. Kelp and soft corals were common in the video records, even in the absence of hear? rock coverage. [n general, .the findings of the geophysical surve), are in agreement with direct seabed observations. Geophysical estimations of rock cover were often higher than those made from direct observations. This overestimation reflects the generally conservative approach taken in interpreting the geophysical data. D. Surficial Bottom Features I. Tract 69 a. Ice Gouges ice gouges were observed in the areas illustrated on Plate 6. These areas include varying densities of gouging of the sea bottom and should be considered qualitative. Ice gouges were observed in both the eastern and svestern corners of the survey area. Gouges in clay are particularly well preserved and include both recent and older gouges, one superimposed on the other. All of the gouges observed cut less than one meter into the seabed. .ARDINO-LAW$C~4 A$:SO~IA~ b. _Stiff Clay and Sand Waves The distribution of clay outcrops and sand wave fields for Tract69 is illustrated on Plate 7. The clay, recognized largely by textural characteristics on the Side-scan records, is interpreted to represent outcrops of Pleistocene marine deposits, although in the easternmost portion of the survey area beyond the limits of Tract 69 boring and subbottom data indicate that some of the clay outcrops may be Holocene deposits. Sand wave fields were found predominantly in the central portion o~ Tract 69. They are present in localized areas and often appear to be migrating across clay bottom. The sand wave fields are largely irregular in shape but occasionally exhibit a crescent form. The sand waves are generally less than one-third meter high but were observed as high as three meters from crest to troughs north of the Reindeer-Cross Island-Dinkum sand Ridge. 2. Tracts 06 and 07 Plate 12 shows the areal distribution of ice gouges, sand waves and clay bottom based on features observed on the sonographs. Ice gouging areas of varying density occur in both broad and localized zones throughout the survey area. Depth of incision into the bottom of all gouges observed is less than I meter. Sand waves and clay bottom are restricted to the southern portion of Tract 07 and generally coincide with the thicker accumulation of Holocene marine sediments. E. Thickness of Marine Sediments 1. Tracl 69 The thicknesses of Holocene and Pleistocene marine sediments are presented on the Isopach Map, PlateS. Definition of these two geologic units is based on correlation of boring logs with the seismic reflection profiles. Examples of this correlation are also shown on Plate 8. ~'~'q, ARDING-LAW$C)N ASSC)C~IAT~S Shaded patterns on Plate8 represent Holocene material greater than two meters thick. These areas coincide with both shoals and where rock cover and stiff clay outcrops are absent. The thickest accumulation of Holocene materials is six meters, observed in one localized area. This area is also shown on Plate 8. Pleistocene marine sediments (QPm) underlie the Holocene material. The combined thickness of the Pleistocene marine and Holocene deposits is shown at a 2-meter isopach contour interval on the plate. Boring logs indicate that the Pleistocene marine sediments are stiff silt and clay. The lack of internal structure (bedding) seen on seismic profiles indicates that this material is probably quite homogeneous. The base of the unit is represented by a strong continuous reflecting horizon on the profiles. Boring logs indicate that this horizon is the top of the Pleistocene alluvial deposits which consist of interbedded sand and gravel. The combined thickness of the Pleistocene marine and HoIocene sediments ranges between 22 and 30 meters. The thickest accumulations are found in the eastern area of Tract 69. Undefined areas shown on Plate $ are due to acoustic anomalies on the seismic profiles. 2. Tracts 06 and 07 Thickness of Holocene marine deposits is shown on Plate 13. The thickness ranges from less than I meter to, 9 meters, with the average thickness about 3 meters. Thickest accumulations are in the southeast portion of Tract 07. Much of the area has erratic accumulations that are between 2 and 0 meters. In most cases the Holocene sediments consist of Sandy silt and directly overlie Pleistocene alluvium: However, previous studies have indicated that in some places the alluvium may also be overlain by a thin unit of stiff Pleistocene marine sediments. /b IAllDING-LAW$ON A$~IAI~$ 'F. Acoustic Anomalies The high-resolution seismic reflection records obtained in Tracts q6, q7 and 69 contain zones where definition of the subbottom structure is poor. These areas are shown on Plates 9 and 13. The anomalous zones generally occur within 5 to 15 meters of the seabed. They are the result of high signal attenuation. Two distinct anomaly types have been identified and have been categorized as total seismic signal attenuation and partial signal attenuation. Total signal attenuation is characterized by an abrupt loss of reflected signal and truncation of subbottom reflecting horizons at the boundaries of an acoustically turbid zone. A partial signal attenuation zone has a weak reflected signal causing limited seabed penetration so that the subbottom horizons are faint and poorly defined. Examples of both anomalies are shown on the seismic reflection profile segments on Plate 9. The zones of total signal attenuation are similar in nature to acoustically turbid sediments described in a study by Schubel and Schiemer (1972). This study shows acoustically turbid sediments have a high compressibility due to the presence of interstitial gas bubbles. The source of the gas may be either biogenic or petrogenic. Several test borings carried out in the acoustic anomaly areas (HLA/USG5, 1979) have encountered both biogenic and petrogenic gas. The gas concentrations found in the air space in the sample containers and the drill cuttings were: (CI) Methane 30g - 61,071 ppm (62) Ethane 10 - 27t ppm (63) Propane ~ - 67 ppm (Ct) Isobutane 0 - 22 ppm (Ct) Butane 0 - 29 ppm C5-67 (totaL) 2 - 1,019 ppm ! ~ING-LAWSON ASSOC~IAT~S Insufficient data are available to correlate gas concentrations or types with individual geologic units. An adequate number o! samples for unit correlation were obtained from only four MI.A/USGS boreholes. Two of the four boreholes were entirely within the Pleistocene marine (QPm) unit so that only two boreholes are available for correlation of gas concentrations in both Holocene and Pleistocene geolo§ic units. The closest of these tsvo boreholes to the study area was HLA/USGS Boring 12 (see Figure 2). Eleven samples obtained from Borehole 12 (8 from qPm and 3 from QPa) showed gas concentrated in the QPm. A11 marine samples were taken in clay units whereas the alluvial samples were taken from sandy sections which may have afforded ample opporturdty for the escape of trapped gas. Zones of partial signal attenuation may be more directly related to areas of the sub-seabed having high concentrations of organic material. Peats have been cored throughout Stefansson Sound. The peats are present as thin lenses within both fine-§rained Holocene and Pleistocene deposits. RESULTS OF THE ClDS LOCATION SURVEY, BEAUFORT SEA, ALASKA AUGUST 1987 Prepared for: AMERADA HESS CORPORATION P.O. Box 20qO Tulsa, Oklahoma 7q102 NORTEC A DIVISION OF CONTENTS Report Plates 1 - 3 Plate 1 - Drill Site/CIDS Pad Bathymetric Survey Plate 2 - Drill Site Reference Map Plate 3 - Side Scan Sonar Reference Map Side Scan Sonar Record #1, Line 202 Side Scan Sonar Record ~2, Line 203 Side Scan Sonar Record #3,' Line 204 RESULTS OF THE CIDS LOCATION SURVEY, BEAUFORT SEA, ALASKA On 2 August 1987, NORTEC performed a precision depth and side scan sonar survey at the proposed CIDS drill location site in the Beaufort Sea, Alaska. We used a MiniRanger III and associated data processor peripherals for positioning and data acquisition, respectively, a Ross Laboratories 801/603 System for echo sounding, and a Klein 500 KHz side scan sonar system for conduc- ting the seafloor hazards survey. The results of the precision depth survey showed that the sea- floor was very flat with an average depth of about 42 feet, MLLW. Corrections to sea level were made using tidal data obtained from a local tide gauge on West Dock. All perturbations of the sea- floor appear to be less than approximately + 1 foot. A spot elevation bathymetric map is presented on Plate 1. The center box represents the drill site. A drill site reference map is presented on Plate 2. Included on this map are the Alaska State Plane Coordinates (Zone 4) and the latitude and longitude for the drill site center point, the 4 closest bore holes and the four corners of the box representing the drill site. The side scan sonar reference map is presented on Plate 3. During the survey, seven lines were run across a 600' x 600' block centered on a 400' x 400' area under study for drilling with the CIDS drilling platform. The side scan sonar lines were run in an east-west direction. The side scan fish was towed from the bow of a Crowley tug at approximately 3-4 knots. The sea state was choppy with 0.5-1 foot swells. Some sea noise does appear on the side scan sonar records, but does not mask any useful data. The following is a line by line description of the results of this survey: Line 202 - Run west to east. The seafloor appears flat with no observed objects above average bottom depth. The side scan sonar record shows 2 small drag marks, one on the starboard side at timing mark 15:24 and one on the port at 15:24:30. Line 203 - Run east to west. The seafloor appears flat with no significant relief. No objects were detected above average bottom depth. One very small drag mark was noted at timing mark 15:27:30. Drag mark depth appears less than one (1) 'foot relief. '1 Line 204 - Run from west to east. The seafloor appears flat with no observable relief. No objects were detected above the average bottom depth. Seafloor drag marks were not detected on this section of the record. In summary, all side scan sonar records show no significant ice scour or objects above the bottom depth. 10.0 'STAND ALONE VOLUMES The following stand alone volumes are submitted herewith as supporting documentation for the Amerada Hess Corporation Northstar- No. 3 application for Permit to Drill: (1) Plan of Operation, Northstar No. 3 Exploratory Well, prepared for Amerada Hess Corporation. NORTEC, A Division of ERT, July, 1987. (2) Geotechnical Investigation, Site B, Northstar - Seal Area, Beaufort Sea, Alaska. Final Report EBA Engineering, Inc. Project No. 0501-4667, July, 1987. (3) Hydrogen Sulfide Contingency Plan for Northstar NO. 3 Exploratory Well. NORTEC, A Division of ERT, August, 1987, environmental and engineering excellence ANCHORAGE, ALASKA NEWBURY PARK, CALIFORNIA FORT COLLINS, COLORADO WASHINGTON, D.C. LOMBARD, ILLINOIS CONCORD, MASSACHUSETTS PITTSBURGH, PENNSYLVANIA DALLAS, TEXAS HOUSTON, TEXAS SEATTLE, WASHINGTON NORTEC A DIVISION OF ~.i17 (907) 276-4302 (805) 499-1922 (303) 493-8878 (202) 463-6378 (312) 620-5900 (617) 369-8910 (412) 261-2910 (214) 960-6855 (713) 520-9900 (206) 881-7700 PLAN OF OPERATIONS NORTHSTAR NO. 3 EXPLORATORY WELL AMERADA Prepared for HESS CORPORATION NORTEC A DP/ISION OF ~T July, 1987 PLAN OF OPERATIONS NORTHSTAR NO. 3 EXPLORATORY WELL Prepared for AMERADA HESS CORPORATION NORTEC, A DIVISION OF ERT ANCHORAGE, ALASKA July, 1987 RE£EIYED AUG 2 4 198/ TABLE OF CONTENTS ].0 STATEMENT OF PURPOSE ................ 1 1 Coastal Zone Consistency Certification .... 1.2 Authorization ................. Page 2.0 SITE LOCATION ................... 3.0 SITE DESCRIPTION .................. 3.1 Sea Ice and Oceanographic Considerations . . . 4.0 SHALLOW GEOHAZARD ASSESSMENT (Stand Alone Volume) . 4.1 Bottom Founded Structures ........... 4.2 Future Investigations .............. 11 14 15 5.0 PHYSICAL ENVIRONMENT ................ 5.1 Meteorology .................. 5.2 Currents, Tides and Storm Surges ....... 5.3 Sea Ice .................... 16 16 17 19 6.0 BIOLOGICAL ENVIRONMENT ............... 6.1 Primary Productivity ............. 6.2 Zooplankton .................. 6.3 Benthos .................... 6.4 Fish ..................... 6.5 Marine Mammals ................. 6.6 Coastal and Marine Birds ........... 6.7 Threatened or Endangered Species ....... 6.8 Effects of Proposed Activities ........ 7.0 PROPOSAL DEVELOPMENT SCENARIO ........... 21 21 22 23 28 30 37 40 44 45 TABLE OF CONTENTS (CONT'D) 8.0 DRILLING VESSEL DESCRIPTION ............ 8.1 Marine Specifications ............. 8.2 Drilling Specifications ............ 8.3 Wastewater, Cuttings and Drilling Fluids Disposal ................... 8.4 Solid Waste Disposal ............. 8.5 Air Emissions ................. 8.6 Communications ................ 8.7 Food Service ................. 9.0 SUPPORT SERVICES AND TRANSPORTATION ........ ]0.0 DRILLING PROGNOSIS (Public Information) ...... 10.1 Geological .................. 10.2 Mud Logging and Collection of Cuttings Samples 10.3 Wireline Logging Program and Velocity Survey . 10.4 Conventional and Sidewall Coring ....... 10.5 Geochemical and Paleontological Program .... ]0.6 Drilling Mud Program ............. 10.7 Casing and Cementing Program ......... 10.8 Testing Program, Disposal of Produced Test Fluids .................. 10.9 Qualifications of Key Personnel ........ Page 48 50 56 66 68 68 68 69 69 71 72 72 73 74 75 75 76 77 78 11.0 BLOWOUT PREVENTION PROGRAM AND EQUIPMENT ...... 12.0 OIL DISCHARGE CONTINGENCY PLAN (Stand Alone Volume) ................ 80 84 -- TABLE OF CONTENTS (CONT'D) Page 13.0 HYDROGEN SULFIDE CONTINGENCY PLAN ......... 84 14.0 CRITICAL OPERATIONS CURTAILMENT PLAN ........ 85 15.0 ENVIRONMENTAL TRAINING PROGRAM ........... 88 16.0 RELIEF WELL DISCUSSION ............... 89 17.0 REFERENCES CITED .................. 91 iii LIST OF ILLUSTRATION PLAN OF OPERATIONS NORTHSTAR NO. 3 Page Figure 1: Location Map ................. 3 Figure 2: Exploratory Well Location and Adjoining Lease Blocks ................. Figure 3: Ice Thickness, North Coast of Alaska ..... 8 Figure 4: Unconfined Compressive Strength of Ice .... 9 Figure 5: Ice Strength vs. Depth From Top of Ice .... 10 Figure 6: Location of Bird Colonies and Nesting Sites in Vicinity of Project Area ...... 39 Figure 7: Locations of Bowhead Whale Sightings in Project Area ................. 42 Figure 8: Schedule of Activities, Northstar No. 3. . . 46 Figure 9: Conceptual Drawing, CIDS Rig ......... 49 Figure 10: Proposed Ice Road Routing .......... 70 Figure 11: 211/4" Diverter System ............ 81 Figure 12: 135/8'' 10,000 psi wp BOP Stack ........ 82 iv LIST OF TABLES PLAN OF OPERATIONS NORTHSTAR NO. 3 Page Table ]: 10-year Westerly storm, Northstar No. 3 Location ................... Table 2: Table 3: List of Benthic Species Collected in Prudhoe Bay and Simpson Lagoon Areas ..... 24 Estimated Quantities of waste Materials Generated from Northstar No. 3 Exploratory Well ..................... 67 AMERADA HESS CORPORATION NORTHSTAR NO. 3 PROJECT PLAN OF OPERATIONS 1 . 0 STATEMENT OF PURPOSE The Northstar No. 3 project consists of drilling up to three (3) exploratory wells from a bottom-founded mobile offshore drilling unit for the purpose of evaluating the hydrocarbon potential of the Ivishak and other formations in the Northstar-Seal Island area, north of Long Island, Beaufort Sea, Alaska. The initial well (Northstar No. 3) will be drilled as a straight hole to a true vertical depth of approximately 11,350 feet. Bottom hole locations and depths of any subsequent wells will be determined following evaluation of test results from the initial well. The proposed activity lies within the boundaries of State of Alaska lease No. 312799 (Tract BF-47), Joint Federal-State Beaufort Sea Oil/Gas Lease Sale Area. The exploration activities proposed herein are directed toward a further evaluation of the same structural trend that has been previously explored from wells on Northstar Island and Seal Island. Recent drilling from these two man-made islands have shown potentially commercial accumulation of oil and gas in that area. The proposed exploratory well(s) will further assess reservoir characteristics in the area between the two islands. The exploratory well(s) will be operated by Amerada Hess Corpor- ation (AHC) of Tulsa, Oklahoma and New York City, New York. AHC is undertaking this project acting for themselves, without partners. AHC will be the permittee of record for all activities described in this Plan of Operations. -1- The drilling contractor will be Applied Drilling Technology, Inc. (ADTI), based in Houston, Texas. ADTI is a wholly owned sub- sidiary of Global Marine Incorporated. The contactor will use the Concrete Island Drilling System (CIDS) "GLOMAR BEAUFORT SEA I" rig for this project. 1.1 Coastal Zone Consistency Certification The activities proposed in the Plan of Operations conform with the State of Alaska Coastal Zone Management Program and will be conducted in a manner consistent with the objectives of that program. Consistency has been certified in the application for a permit from the U.S. Army Corps of Engineers. 1.2 Authorization The requirement and authorization for this Plan of Operations is contained in Alaska Administrative Code (AAC) 83. 158 and Alaska Statute (AS) 38.05.020, 38.05. 130, 38.05. 145 and 38.05. 180. 2.0 SITE LOCATION The proposed Northstar No. 3 exploratory well is located in the Beaufort Sea approximately 3 miles northeast of the central portion of Long Island and 15 miles northwest of the community of Deadhorse, Alaska (Figure 1 ). Water depth at this location is approximately 42 ft MLLW. Two additional directional exploratory wells may be drilled from this same surface location. The coordinates of this surface location are shown below: GEODETIC POSITION ~UTM. ZO..NE ~6 (I~N. ,METERS ) Lat. = 70 ° 30 ' 41 . 87" Long. = 148°46'02.20'' y = 7,823,756.55 x = 434,105.73 -2- fNORTHBTAR ISLAND ~Propoaed Location ~ Northstar No. 3 IADL 312799 ~ 4). BEAUFORT 148° 30' EGG ISLAND ~ "~~UMP ISLAND POINT STORKERSEN ~7~' POIII~YRL~ WEST DOCK BASE CAMP REINDEER ISLAND ARGO ISLAND SEA' NIAKUK GULL ISLAND · ~ ISLANDS PRUDHOE BAY EAST DOCK :0 BASE I_ r SCALE IN MILE8 (APPROX.) NORTHSTAR NO. 3 BEAUFORT SEA, ALASKA LOCATION MAP Figure 1 N'ORTEC, A DIVI810N OF ERT JULY 1987 DEADHORSE -3- ASPC ZONE 4 (IN FEET) LEASE LINE REFERENCE y = 6,038,273.87 ft x = 650,630.26 ft 11,012.84 ft NSL 4,284.09 ft EWL Lease block BF-47 (ADL 312799) The bottom hole location of the first well to be drilled (North- star No. 3) will be approximately the same as the surface location, as the well is programmed to be a straight hole. The bottomhole location will be well in excess of the required 500 ft distance from the closest lease line. The bottom hole locations of possible subsequent wells, (Northstar 4 and 5) will be approximately 5,000 ft to the SW and SE of the surface location. These bottomhole locations will be further refined following evaluation of data from Northstar No. 3. Both the surface and all bottomhole locations fall within the boundaries of State of Alaska Oil and Gas Lease No. ADL 312799 (Figure 2). 3.0 SITE DESCRIPTION The proposed drilling location lies approximately halfway between Northstar Island and Seal Island. Both of these islands are man-made gravel structures from which drilling has been carried out in the past. Due to the distance from both Seal and North- star (approximately 2.5 miles) it is not practical to direction- ally drill to the desired target from either island. Water depth at the Northstar No. 3 location is 42 ft MLLW. The bottom is relatively flat, but NOAA published bathymetry in- dicates the sea floor slopes up to 5 feet per mile to the North. Amerada Hess Corporation will run a detailed bathymetric survey (50 ft grid) over the proposed site prior to mobilizing the drilling unit. -4- T N T 13 N T i I Shell et al , RI3E ,AMOCO ~ I EXXON I AOL-$12798 i AM ERAE~A HESS BF-47 TE t / ~. Shell et al~ Y- 018~ /'1 -/'J' I ...... '1' X\ ~1 ~ I I I SEAL x ~ ~ ISLAND I ...~, I I I \ I '~, SEAL NO. 2 i % ~ I 3 Mile Li~i' . TEXAS EASTERN AOL- 3~2808 I ...... ADL- 3128Oq t I one mile NORTHSTAR NO. 3 BEAUFORT SEA, .ALASKA EXPLORATORY WELL LOCATION, ADJOINING LEASE BLOCKS AND WELLS PREVIOUSLY DRILLED IN THE AREA NORTEC, A DIVISION OF ERT JULY 1987 II Figure 2 3.1 Sea Iceland Oceanographic Considerations Since operations at the Northstar No. 3 location will be carried out continuously during the winter months, an understanding of the formation and movement of sea ice in the area is fundamental to the integrity of the operation. Water depth at the Northstar No. 3 location is 42 feet. The location is well within the landfast ice zone, since the seaward extent of the floating fast ice is typically near the 65 foot bathymetric contour (Reimnitz et al., 1977; Kovacs and Mellor, 1974). The landfast ice zone comprises primarily seasonally formed ice that is bounded by either the shear zone or grounded fast ice (stamuki zone) at its seaward side, and by bottom fast ice at its shoreward side (Reimnitz et al., 1977). Occasional multiyear ice features can be contained within the seasonal ice, although their distribution is typically sparse. Grounded ice ridges are commonly located within the floating fast ice near the 30 foot bathymetric contour (Kovacs and Mellor, 1974). These ridges are formed through shearing and crushing movements at the landfast ice edge. Grounded ridges help to stabilize the landfast ice zone, preventing invasion by moving pack ice and limiting velocities of shoreward ice (Agerton, 1981; Agerton and Kreider, 1979). Ice movements were monitored at three stations during May, 1984 by Arctec Inc. for Amerada Hess Corporation. Two of the stations were located within Tract BF-46, the third station was situated approximately 2 miles north of Tract BF-46. There were no major ice movements during the period of observation. Maximum recorded movement during a five minute sampling period was less than 0.1 feet and maximum recorded movement during the period of obser- vation was 3.4 feet. -6- The thickness of the landfast ice is dependent upon the time of year. The rate of ice growth has been documented by Tomas (1980). Generally, the maximum thickness of first year landfast ice is about six feet (Figure 3). The most important property of first year ice is its compressive strength. The design crushing strength is dependent upon the rate of loading and the temperature and salinity within the ice. Typical first-year ice has a top surface temperature of approxi- mately -]0°C and a salinity of about five parts per thousand. Compressive strength test results for these conditions are presented in Figure 4. It is evident from this figure that the compressive strength of the ice increases substantially with strain rate up to a maximum of 540 psi at a strain rate of about 5x10-4 sec-1 after which there is no further increase in strength regardless of strain rate. The compressive strength over the full thickness of the ice sheet has been compared with the compressive strength of the top of the ice sheet by Schwarz and Weeks (1977) . Data pertinent to strength variations within ice sheets that are 0.7, 2.6, and 9.8 feet thick are presented in Figure 5. It can be deduced from this figure that the average compressive strength of an ice sheet is approximately 75 percent of the top surface strength, regard- less of ice sheet thickness. Therefore, an average compressive strength through the ice sheet of 405 psi (0.75x540 psi) has been used for design purposes. For late winter ice conditions (six foot thick first year ice sheet) the maximum ice force per foot of width of structure has been calculated to be 350 kips/foot. The oceanographic conditions expected at the Northstar No. 3 location have been estimated using previous work performed by Shell Development Company for the Seal Island site. Because the Northstar location is only 2.5 miles northwest of Seal Island and lies in a comparable water depth, the findings of the Seal Island oceanographic study may be applied directly to the Northstar 6 I i I I I i i I ,~e· o~ · o ~ - ,so~ ~. ~,~o~ ~^~oo~ - · ,~~ ~ , o ~o~/ , ~oo~.t o~,,~, ,. OCTOBER DECEMBER FEBRUARY APRIl.. JUNE NOTE: Adapted from Thomas, 1980 Figure 3 Fast Ice Thickness, North Coast of Alaska 1970 - 1973 -8- 1000 500 100 - . 10-7 · · · · · o · · REPRESENTITIVE COMPRESSIVE STRENGTH · A.P.I. O Schwarz and Weeks I I ! [ I 10-6 10'5 10`4 10'3 10'2 STRAIN RATE (1/sec) NOTE: Adapted from American Petroleum Institute, 1982 and Schwarz and Weeks, 1977 Figure 4 Unconfined Compressive strength of Ice vs. strain Rate. -9- STRENGTH OF SALINE ICE STRENGTH OF FRESH WATER ICE 0.2 0.4 .0.6 I i~.~.~.,~.,~- I 0.7 FOOT T. HICK 2.6 FOOT THICK ICE SHEET 0.8 I ! I 9.8 FOOT THICK ICE SHEET ! ! ! 1.0 NOTE: Adapted from Schwarz and Weeks, 1977 Figure 5 Ice Strength vs. Depth 'from Top of Ice. -10- site. The previous studies by Shell (Reese, 1981a, Reese, 1981b; Ward and Reese, 1979) have utilized numerical modeling techniques to determine the expected wave conditions within the area. Table 1 summarizes the oceanographic conditions during a 10 year westerly storm event. Sea ice, oceanographic, and meteorological conditions at the site are further discussed in Section 5.0 (Physical Environment) herein. 4.0 SHALLOW GEOHAZARD ASSESSMENT (Stand Alone Volume) EBA Engineering, Inc. (EBA) conducted a geotechnical investi- gation of the proposed site, as well as three alternative locations, in April 1987. The investigation was carried out from the ice and involved four (4) sampled borings at each site. In situ core penetrometer testing (CPT) was performed as well as comprehensive laboratory testing of recovered samples. An interim report covering the geotechnical conditions at the proposed location (EBA referenced "Site B") is submitted herewith as in a stand alone volume and entitled "Geotechnical Investigation Site B, Northstar-Seal Area Beaufort Sea, Alaska". The conclusion drawn from this interim report is that the proposed site is suitable for the deployment of a gravity structure such as the CIDS Beaufort Sea I. The dense sands and gravels present at the site will offer good frictional resistance to lateral ice loading, and vessel mud skirt penetration and withdrawal can be accomplished with the limits of available ballast and buoyancy forces. Stratigraphic conditions on the inner Beaufort Sea shelf in the area of the proposed location have been influenced by a complex series of sea level fluctuations occurring during the Pleisto- cene. During these fluctuations, in which the sea level may have reached elevations of 300 feet above and 400 feet below present Table 1. Ten Year Westerly Storm, Northstar No. 3 Location. Oceanographic Condition Design Criteria Water Depth (MLLW) 42.0 feet Storm Surge 2.7 feet Astronomical Tide 0.7 feet Significant Wave Height 12.0 feet Maximum Wave Height 22.8 feet Significant Period (Ts) 9.6 seconds Mean Period (T) 8.7 seconds -12- levels, the shelf has been subjected alternately to continental and marine deposition and subaerial exposure. Most of the · Quartenary deposits in the area comprise alluvial and fluvial materials deposited during sea level regressions. Surficial Holocene materials comprise marine sediments deposited during the most recent transgressions, together with reworked Pleistocene soils and present day deltaic and littoral deposits. Surficial soil conditions at Site B comprise two distinct units: a thin mantle of soft or loose Holocene silts and silty sands, overlying dense Pleistocene sands and gravels. Detailed in- formation is presented in the Stand Alone Volume. The strati- graphy is summarized in the following table: SOIL DESCRIPTION SILTY SAND, fine, loose; and SANDY SILT, soft to medium; trace of organics, trace of gravel SAND, medium dense DEPTH RANGE TO TOP OF LAYER (feet) RANGE OF THICKNESS ( feet ) 0 4.5 - 8.0 5.0* 0 - 2.5 SANDY GRAVEL, clean, dense to very dense, up to 2.5" sizes; frozen below 54 feet 4.5 - 8.0 >25 NOTE: * where present A thin veneer of loose silty sand appears to exist at the seabed surface across the entire site. The soft sandy silt was en- countered at all boring locations, but in general was thinner in the eastern portion of the site. The surface of the sandy gravel is closest to the seabed surface in the eastern portion, occur- ring at a depth of approximately 4.5 feet. Gravelly sand layers exist within the Pleistocene strata and a frozen gravel encountered at 54 feet is well bounded with no excess ice. A shallow geologic hazard survey was conducted in the area by Harding-Lawson Associates (HLA) in summer of ]980, and an over-the-ice geotechnical investigation carried out by the USGS and HLA in ]978 acquired data in the area as well (Borings 4 & 5, HLA/USGS). An additional shallow hazard survey was con- ducted in 1984 by HLA for Amerada Hess Corporation which centered on the NORTHSTAR "A" Island location. In general, the HLA shallow hazard surveys indicate that the seabed at the proposed site is fairly regular and slopes upward to the south toward Long Island. Numerous ice gouges were detected on earlier side scan sonar records. The proposed location lies in the floating fast ice zone and rafting of floes during freezeup and breakup can produce keels which can gouge the seafloor to a depth of one to two meters. The depth of incision of all gouges observed was interpreted to be less than one meter. High resolution seismic reflection records in Tracts BF-46 and BF-47 indicate only one small area of signal attenuation indi- cative of acoustically turbid sediments having a high compres- sibility due to the presence of interstitial gas bubbles. This area is located over 6 miles to the southeast of the proposed location. No signal attentuation indicative of hydrocarbon presence was obserVed in the area of the proposed location. Seismicity of the area is very low. 4.1 Bottom-Founded Structures A major issue governing the design of bottom-founded structures for the Beaufort Sea is the provision of adequate lateral resistance against ice loading. The lateral resistance is a function of the shear strength of the seabed soil at the govern- -14- ing potential failure surface. Depending on whether the soil behaves in a frictional or cohesive (undrained) manner, the sliding resistance may also depend on the on-bottom weight, base area, and the efficiency of the contact between base and soil. The efficiency of contact depends to some extent on the nature of the seabed surface and, for a structure with base shear (mud) skirts, such as the CIDS, on the mode of action of the skirts. The latter is also influenced by the resistance to penetration of the skirts. For bottom-founded structures designed for the Beaufort Sea, bearing capacity is seldom a problem, due to the small thickness of potentially weak material in relation to the width of the structure. The near-surface Pleistocene soils present in the Seal-Northstar area will provide adequate assurance against bearing failure. Settlements may occur, however, particularly if the applied load exceeds the preconsolidation pressure of the surficial sediments. The most critical layer with respect to sliding resistance at the proposed site is the soft sandy silt. This material displays an in situ undrained shear strength in the range of 400 to 600 psf. Under loading by a structure, this value will increase somewhat due to consolidation, a process that would be reasonably rapid due to the relatively permeable nature of the soil. 4.2 Fu~ture Inve. s_~tigation.s Prior to mobilizing the CIDS Beaufort Sea I to the drilling location, Amerada Hess Corporation will conduct a detailed bathymetric and side scan sonar survey. Any significant anom- alies discovered by these surveys will be 'further investigated by divers. The results of these further site investigations will be made available to the Alaska Oil and Gas Conservation Commission and the Department of Natural Resources. 5.0 PHYSICAL ENVIRONMENT 5.1 Me. t. eor0 loggy Long-term temperature data are available for Barrow, Barter Island, and Prudhoe Bay. Air temperatures at all three locations are very similar with mean annual temperatures in the range of -12 to -13°C (10° to 9° F). All stations show mean monthly temperatures below freezing except in June, July and August. July temperatures (3.7 to 4.6°C [39 to 40°F]) are the warmest and February (-28 to -31°C [-18 to -24°F]) is the coldest month. Precipitation is minimal in the project area. The annual precipitation (including the water content of the snow) and snowfall data for Barrow and Barter Island have been obtained by the National Weather Service for the last 40 and 26 years, respectively. These data indicate a mean precipitation in ~the range of 12 to 18 cm (5 to 7 inches) annually. The prevailing winds along the Beaufort Sea coast are from the east and west (Selkregg, 1975). The mean annual wind speed for Barrow, Barter Island, and Prudhoe Bay is 10.3, 10.5 and 11.5 kts, respectively. The mean annual direction is easterly for all locations. There is some seasonal variation in both wind speed and direc- tion. Mean monthly wind speeds are generally highest in winter and lowest in summer. Although wind directions vary somewhat, they are generally from either the east or the west. During the summer, the prevailing direction is from the east. Highest winds on record (fastest mile) for Barrow, Barter Island and Prudhoe Bay are 50.5, 80.5, and 50.5 kts, respectively. Highest winds, unlike the prevailing winds, are generally from the west and are more common in the fall and early winter than in the spring and summer months. -]6- 5.2 Currents, Tides, and Storm Surges Winter current measurements by NORTEC (1981) in Stefansson Sound in water depths of 5.5 to 8.2 m (18 to 27 ft) indicated average currents of less than 2 cm/s (0.04 kts) with occasional pulses to 10 cm/s (0.2 kts) or greater. The duration of these pulses generally ranged from several hours to several days. Current directions were generally either easterly or westerly for both the normal and extreme currents and did not appear to correlate with either winds or tides. Woodward-Clyde (1979) measured below-ice currents at six locations in water depths of 4.0 to 7.5 m (13 to 25 ft) in the vicinity of the West Dock at Prudhoe Bay. Although current speeds were similar to those reported by NORTEC (1981), their data suggested a tidal dominance in currents. It is expected that these tidal effects are more predominant in nearshore areas, particularly in the vicinity of passes between barrier islands or at bathymetric constrictions. Currents and circulation patterns in the nearshore areas during the open water periods are primarily wind induced (Kinney et al., 1972, 1975; Britch et al., 1983; NORTEC, 1983). Prevailing easterly and westerly winds, in combination with the general east-west orientation of the shoreline and bathymetric contours result in a predominance of westerly or easterly currents along most of the nearshore areas. Based on current measurements in Stefansson Sound (Mangerella et al., 1979; Britch et al., 1983), mean currents would typically range from 10 to 15 cm/s (0.2 to 0.3 kts) with maximum currents typically in the order of 50 to 60 cm/s (1.0 to 1.2 kts). Although open water currents have not been measured at the drilling site, it is expected that they would be similar to those indicated above. Tides in the area include both astronomical and meteorological components. Astronomical tides are the result of a complex interaction of gravitational forces of the sun and the moon and hydrodynamic responses imposed by the basin geometry on these forces. Storm surges, or meteorological tides, result as shear stresses imposed by strong winds move near-surface water masses at a greater rate than can be counterbalanced by gravitational forces less shear forces at the seafloor. Storm surges may either be positive (above normal sea level) or negative (below normal sea level) and generally produce greater water level changes in the area than the astronomical tides. The following sections describe astronomical tides and storm surges documented for the project area. Astronomical Tides - Tidal data are available for a number of locations along the Beaufort Sea in the vicinity of the drilling site. Based on these data the astronomical tides in Stefansson Sound are classified as mixed (and mainly semidiurnal) and are characterized by two unequal high and low water levels occurring over a lunar day (24.8 hours). All stations report mean and diurnal ranges of 12 and 18 cm (4.7 to 7.1 inches), respectively. Storm Su~r. ges - While astronomical tides are of academic interest, the largest variations in water levels in the study area, at least during the open water periods are attributed to storm surges. Perhaps the most dramatic storm surges on record occurred in September, 1970. Low-lying tundra plains and deltas as far as 5.0 km (3.0 mi) inland were inundated and a driftwood line was left as much as 3.4 m (11.2 ft) above t.he normal sea level (Reimnitz and Maurer, 1978, 1979). Surge elevations measured along the coast near the study area ranged from 2.3 m (7.5 ft) near Spy Island to 2.6 m (8.5 ft) southwest of Oliktok Point. Although winds from the 1970 storm of 45 kts, gusting to 70 kts, were reported to have a return period ranging from 25 to 50 years, the actual surge has been estimated to have a recur- -18- rence interval of approximately 100 years (Reimnitz and Maurer, 1978, 1979). A number of other meteorological events produced surges which are worthy of mention. A storm in August, 1975 generated a 3 m (10 ft) surge at Prudhoe Bay. A severe storm in October, 1963 generated a 3.7 m (12 ft) surge at Barrow (Hume and Schalk, 1967). A September, 1957 storm generated a 1.8 to 3.7 m (6 to 12 ft) surge at Barter Island. The village of Kaktovik was flooded with 0.1 m (0.3 ft) of water during an August, 1972 storm (Wise et al., 1977). Although open seas are generally considered to be a prerequisite for storm surges, they have been known to occur during periods of complete ice cover. Reimnitz and Maurer (1978) report obser- vations of three surges with heights of 69, 94 and 150+ cm (27, 37 and 55+ inches) occurring near Oliktok Point in January and February, 1973. Other observers have documented flooding of large areas of grounded fast ice, presumably due to storm surge events in the floating fast ice areas. Reimnitz and Maurer (1978) further indicate that winter surges have not always coincided with storms and suggest that driving mechanisms other than wind may be responsible for these events (other mechanisms were not identified). 5.3 Sea Ice The Beaufort Sea ice season persists for up to nine or ten months each year. -The season begins with ice formation in late Sep- tember and ends with ice melting and breakup in June or July. Even during the brief open-water period, ice may be present in the form of floes of ridged or multi-year ice. Sea ice begins to develop in late September forming first on surface waters adjacent to river mouths and coastal lagoons (Reimnitz and Barnes, 1974). During winter, ice forms from the -19- sea surface downward and achieves a normal maximum ice thickness of 1.8 to 2.1 m (6 to 7 ft) by April. Thicker ice may be found locally because of ice rafting or ridging. In May, melting begins at the ice surface and melt ponds appear on the sea ice surface. These ponds increase in area and depth as spring continues, eventually draining through cracks and holes in the sea ice (Barns and Reimnitz, 1974). By late May or early June, melting rivers in the area usually reach the Arctic coastline. River channels and nearshore areas near the Colville River, the Kuparuk River, and the Sagavanirktok River are generally shallow and intermittently frozen to the bottom by late winter, and river floodwaters in part, spread out on top of the sea ice. The outer limit of over flood ing typically extends only a short distance seaward of the outer edge of the bottomfast ice edge. Walker (1974) indicates that overflow from the Colville River normally forms an arch nearly parallel with the delta front over the 3 to 6 m (10 to 20 ft) contours. River over-flooding from either the Kuparuk or Colville Rivers is not expected to be present at the proposed island site. Open water along the Arctic coast begins with the river over- flooding, and as summer progresses, sea ice breakup proceeds normally from the shore in a seaward direction. This breakup process can be accelerated by summer storms. Although remnants of the melting and broken ice can be absorbed into the seaward retreating ice pack, the area is rarely completely ice free, and floes consisting of multiyear ice, or ice ridge fragments can persist throughout the summer. Ice road construction over floating sea ice can begin as early as mid-December. Weakening of the sea ice as breakup approaches usually forces the road to be abandoned by mid-May. -20- 6.0 BIOLOGICAL ENVIRONMENT · The Beaufort Sea supports numerous coastal and marine species whose distribution varies temporally. Most animals are absent from the Beaufort Sea area from freeze-up to the following ice breakup. In the spring, most marine mammals are found several miles offshore along the transition zone between the landfast and moving pack ice. Most birds, fish, and mammals show a high degree of mobility and specialized adaptations to survive in an environment characterized by extremes of physical and biological parameters. General descriptions of the biological resources of the Beaufort Sea are provided in the following sections. 6.1 Primary Productivity Primary production in the Beaufort Sea is furnished by phyto- plankton, ice algae, and benthic algae. Annual production in the Beaufort Sea is relatively low, i.e., less than 20 grams of carbon per square meter per year (gC/m2/yr) (Carey et al., 1978). By comparison, annual production in the Bering Sea is estimated at 121 gCm2/yr (McRoy and Goering, 1974). Phytoplankton blooms generally occur in the photic zone (upper water column) in late spring and early summer as a result of ice breakup and lengthening daylight. Phytoplankton abundance appears to be greatest in nearshore waters with decreasing numbers further offshore. Nearshore communities are dominated by both pennate and centric diatoms, and flagellates. Peak abun- dance occurs in late July and early August due to increased light levels (Bursa, 1963; Horner et al., 1974). The phytoplankton bloom accounts for an estimated 31 percent of Prudhoe Bay's annual primary production (Horner et al., 1974). Ice algae blooms occur in March and April on the bottom of ice and continue until early June when ice breakup begins (Horner and Schrader, 1982). Pennate diatoms predominate while centric diatoms, flagellates, and cryptomonads occur in lesser numbers (Griffiths and Dillinger, 1981). Ice algae account for less than 10 percent of carbon fixed annually in the Beaufort Sea (Horner et al., 1974), but the timing of the bloom provides an early spring food supply for zooplankton and benthic organisms (Horner and Alexander, 1972; Horner e.,t al., 1974; Carey ~e.t 91., 1978). Benthic macroalgae (commonly associated with boulders) are sparsely and patchily distributed, and make a negligible contri- bution to primary production in the Beaufort Sea (Schell et al., 1982; Dunton et al., 1982). However, kelp do provide important substrate for the attachment of a diverse assemblage of other marine organisms (Dunton et al., 1982). Benthic microalgae generally include diatoms, flagellates, and blue-green algae (Bursa, 1963). Habitats which may be important for benthic microalgae are in clear water in the lee of spits and islands. The overall contribution of benthic microalgae to primary production in the Beaufort Sea remains unknown (MMS, 1984). Project activities are not expected to impact primary production in the Beaufort Sea since effects will be localized and short- term in nature. 6.2 Zoopl ankto_n Over 100 species of zooplankton have been identified for the Beaufort and Chukchi Seas. Zooplankton densities are highest in summer when they graze on phtyoplahkton. Copepods are the dominant group in terms of total biomass and numbers of species. Other planktonic organisms include amphipods, mysids, euphausids, and the larval stages of many benthic invertebrates (e.g., barnacles, polychaetes, hydrozoans, snails, and starfish) (BLM, 1979; MMS, 1984). -22- Project activities are not expected to impact zooplankton populations in the Beaufort Sea since efforts will be localized and temporary in nature. 6.3 Benthos The distribution, abundance, and species composition of the Beaufort Sea benthos are strongly influenced by the physical- chemical environment. Carey e~t al. (1978), Feder and Schamel (1976) , and Crane and Cooney (1973) considered the following factors to be of particular importance to organisms that live on or in the bottom sediments (the benthos) of the Beaufort Sea. 1. ice scour and wave action 2. salinity 3. sediment type and distribution 4. availability of food. Ice scour, wave action, and sedimentation seaward of the barrier islands preclude the establishment of benthic communities similar to the Boulder Patch of Stefansson Sound. Numerous studies have investigated the benthic infauna and epifauna of the Beaufort Sea. NORTEC (1981) investigated the inshore benthic infauna shoreward of the Midway Islands at water depths of 4.9 to 8.2 m (16.0 to 26.9 ft) in 1979. Greater numbers, biomass, and diversity of benthic fauna were noted than in the shallower nearshore areas examined by Feder in 1974 and 1975 (Feder et al., 1976). During the sampling, 165 invertebrate ~ ,111 taxa in 13 phyla were collected (Table 2). Polychaetous annelids (71 taxa) dominated the fauna, while molluscs (36 taxa) and crustaceans (31 taxa) were subdominants. Mean biomass was 55 g/m2 wet weight, and the Shannon function of diversity ranged from 2.4 to 3.0. Table List of Benthic Species and Simpson Lagoon Areas Dillinger, 1981). collected in the Prudhoe Bay (NORTEC, 1981; Griffiths and TAXA TAXA PROTOZOA Unidentified species PORIFERA Unidentified species CNIDARIA Hydrozoa Unidentified species Anthozoa Eunephyta rubiformis RHYNCHOCOELA Unidentified species ASCHELMINTHES Nematoda Unidentified species ECTOPROCTA Unidentified species MOLLUSCA Gastropods Cingula sp. Nat:ca'clausa PolLn~ces paflida Neptunea heros RetUsa sp. Oenopota sp. Oenopota impress~ ~ pyrlm~dali~ ~nopota bicarinat~a Oenopota re~ulat~ (~eno~ota laev~ga~a Oeno~ota nova]asmeliensis {Yenopo~a c:nere~ Cyl~cnna occults Unidentified' species Pelecypoda Nucula tenuis ~ortlandl~ arctics Liocyma ffuctuosa Ps"e p~'zd'a lordL Husculus n~ger ~usculu~ sp. A~tarte borealis ~starte moncegu~ Astarte benneccLi ~start~ esqu~mauli Astarte sp. MySellasp. Th~as~ra qouldi Ax~nops~d~ oro%culata ~xinoDsida sp. Diplooon~a aleutica Macoma moesta alaskans Lyons~a a:enosa :yons~a sp. ~dae, unid. species Unidentified species ANNELIDA Polychaeta Anaitides groenlandica Etoene Me-~is---~eni Phloe m~nu~a Nephtys ciliata Neph~y$ Dunciad__s Agiaop~omus malmgreni E~'o~one naidina Nere~myra apnroditoides Nere~s z6na~a ap~l a~pitata Heteromastus fLl/formis Capfcellidae, unLd. species Scalibre~ma inflatum P~ax~Ilella sp. Praxiliella praetermissa Clymenura Maldanid'~e, uni4. species Traves~a iternaosLs scutata Sp~o sp. p~ filicornis S~--~-~chaetopterus Pr~onospxo Pr:onoip~o cirriferra Spionidae, unid. sp6cies Ar~cidea suecica Aric~dea ~ef~re~sii T~u~er~ ~racilis '" Ap~scoorancnus tullberq~ ApLstoocanch£dae, un~d. species Lumbrineris Lumsr~ner~s fragilis Ninoe ~ ~emmea D--~ll~, unid. species Spinther sp. Haploscoloous elon~atus $coloplos arm~ger Chae:ozone setosa Tharyx sp. ~r~ulidae, unid. species Owenia fusiformis , Amonarete sp. Ampharet~ goesi Ampnare:e vega AmphecteXs Lys~ppe Iabiata Am~~tidae, dnid. species TereDellides stroemi P%sta or,stats Lanaisa venusta prociea sp. Proclea ~raffii Tece0e~lrdae, unid. species Brads eranuLata ~lidae, unfd. species Chone duneri ~-~K~r~sis minuta Unidentified species OIiqocnaeta Unidentified species -24- Table List of Benthic Species collected in the Prudhoe Bay and Simpson Lagoon Areas (NORTEC, 1981; Griffiths and Dillinger, 1981) (Cont'd). TAXA ,TAXA ARTHROPODA Crustacea Podocooa Unidentified species Mysidacea Mysis littorali$ Mys~s rel~cta Mvs~s sp. Cumace~ Lamoroos ~ias~viis 0iastvli's rathkei Diastvlis Brachvdias~&sima Tana:dacea Unidentified species Isoooda Saduria entomon Sadur~a sab~nl Ampn~po~a Bvblis ~aimardi ~ a-'~ oo~s SD. Haolooos sibirica Leotocneirus so. PontoDore~a femora IscnvroceCus A~O~VX Anonvx nu~ax Boeckosimus sp. Boeckoslmus brevis Boec~os:mus ~ Boec~6slmus Hiooomedon sp. O~'fsi~us birulai 0~{s~muS HlaciaLis Onisimds litoralis Bat~Fmedo~ sp. M0nOculo'~des U~id6ntified species Atvlus carinata r~ene sp. O~dicero~ids PRIAPULIDA Halicrvotus soinulosus ~riao61us ~auda:'us SIPUNCULA Golfin~ia marqaritacea ECHINODE~ATA Holo~huroidea Myriotrochus rinkii ~nidentified ~eci~s CHORDATA Unidentified species Teleostei Unidentified species Cottidae, unid. species Griffiths and Dillinger (1981) conducted extensive studies of benthic epifauna in the Simpson Lagoon, Jones Island, and Spy Island areas. Mysids and amphipods were the most abundant invertebrates during the open-water season. Mysis littoralis and M. relicta were the most common mysids while Onisimus glacialis ., , and Boeckosimus affinis were the key amphipods present. B. affinis was the dominant amphipod on the ocean side of the barrier islands while O. glacialis was most abundant on the lagoon side. O. littoralis was also found to be abundant in · deeper offshore waters (9 to 11 .5 m; 30 to 38 ft). Seasonal calculations of biomass showed that mysid species migrated from the lagoon areas to deeper water during freezup while O. glaci-_ alis overwintered in the shallow areas. Both mysid species recolonize the lagoon areas immediately after breakup. Species present in studies by both NORTEC (1981) and Griffiths and Dillinger (1981) were nearly identical. A combined list of all benthos for these two studies is presented in Table 2. Densities and biomass of benthic invertebrate species vary widely in the open-water season. Benthic invertebrates are either filterfeeders (feeding on molts, carcasses, detritus, and living organisms suspended in the water column), or bottom feeders (feeding on organics in the sediments). The quantity and distribution of food and nonfood particles has a major effect on the abundance and distribution of benthic species. Primary production by phytoplankton is probably of major importance (Carey et al., 1974) and epontic algae are also likely to be an important early food source (Horner and Alexander, 1972). The dependence of primary productivity on the ice cover and the turbidity, temperature, salinity, depth, and nutrient supply of the surface waters further ties the success of benthic communi- ties to these physical and chemical factors. -26- Potential effects on benthic communities from placement of the rig on location and exploratory drilling activities include: mortal- ity or physiological stress from physical disruption of the sea bottom including burial of benthic organisms; lethal or sublethal effects as a result of sedimentation from mud and cuttings discharges; altered rates or recolonization in disturbed areas; or changes in community structure as a result of habitat alterations. Turbidity resulting from mud and cuttings dischrages from the rig would reduce light penetration and would interfere to some extent with the operation of gills and filtering organs of filter feeders. Benthic organisms are normally associated with mud or silt and are highly tolerant of most suspended sediment con- ditions caused by construction activities (Hirsch et al., 1978). Studies conducted by the U.S. Army Corps of Engineers as part of the Dredged Material Research Program have demonstrated that concentrations of suspended sediments that are lethal to most marine species are higher than concentrations observed in the field by an order of magnitude or more. Ambient levels of suspended sediments are relatively high in the Beaufort Sea as severe storms, winds, and currents prevent rapid deposition of sediments and suspended surface sediments. Polychaetes and other annelids are generally successful at burrowing through -sediment accumulations. Surface dwelling crustaceans do not fare well under heavy sedimentation; however, many species are adapted to the shifting or gradual accumulation of sediment (Masse, 1972). Bivalves vary in their ability to exhume themselves from sediment accumulation. Some can escape from 50 cm burial (Kranz, 1972) while others are unable to escape from 1 cm accumulation. Habitat alterations will be very localized and will occur primarily in deposition areas. Alterations would consist of changes in sediment grain size, changes in water depth, and possible changes in current, temperature, and salinity. Some impacts may result from the associated ice road which may be constructed to resupply the rig. Infauna would be lost along the corridor where the road's ice thickness allowed contact with the bottom (excluding the corridor in 2 m or less of water, which naturally freezes to the bottom). Mobile epifauna would move away from the affected area. This area is periodically scoured by natural ice, thereby relieving the magnitude of impact. In summary, sedimentation and burial resulting from the proposed drilling operation is expected to have an insignificant impact on the arctic benthic community due to its localized nature. 6.4 Fish The Beaufort Sea and its arctic coast support freshwater, anadromous, and marine fish species. Excluding freshwater species, there have been 43 fish species documented in the Beaufort Sea. The relatively low species diversity, when compared to more than 300 species in the Bering Sea and Gulf of Alaska, has been attributed to low temperatures, low produc- tivity, and harsh ice conditions which prevent extensive use of coastal habitat during winter months (MMS, 1984). Freshwater species distribution is sporadic in coastal waters of the Beaufort Sea, with peak abundance occurring during or immediately after spring breakup. These species are almost exclusively associated with the extension of fresh or brackish waters off 'major river deltas. Freshwater species include arctic grayling, round whitefish, and ninspine stickleback (MMS, 1984). Anadromous species found in nearshore waters of the Beaufort Sea include arctic char, arctic cisco, least cisco, Bering cisco, boreal smelt, humpback whitefish, and broad whitefish. Pink and chum salmon are also occasional occupants of Simpson Lagoon and numerous coastal rivers (Craig and Haldorson, 1981 ). -28- With the first sign of breakup (June 5 - 20), adult and juvenile anadromous fish move into coastal waters to feed on an abundant epifaunal food supply of mysids and amphipods. During the open water months, anadromous species typically occur along the mainland shore (within 100 m) and along the edges and lee sides of the barrier islands. Spawning occurs in river deltas or further upstream in the fall (except for boreal smelt which spawn in spring or early summer). Overwintering areas probably occur in large river deltas (Bendock, 1977; Craig and Haldorson, 1981; Galloway et al., 1982). Anadromous fish are the focus of fisheries along the Beaufort Sea coast. Most subsistence fishing occurs in inland lakes and streams. The only continuous commercial fishing operation on the North Slope is operated by a single family during the summer and fall months in the Colville River Delta. Subsistence catch in the Colville River Delta area is probably similar to the area's commercial catch. Of four species harvested commercially, arctic cisco is the most important. Average annual commercial catch data (1964 - 1981 ) is as follows: Spec ie..s Number Harv~ested* Arctic cisco Least cisco Broad whitefish Humpback whitefish 32,548 20,863 2,030 1,677 *Source: MMS, 1984. It is estimated that about 9 percent of the arctic ciscos and 5 percent of the least ciscos are harvested by commercial fisheries each year. It is assumed that the subsistence fisheries harvest a similar portion of the fish population (MMS, 1984). -29- Marine fish species are widely distributed throughout the Beaufort Sea in low densities; although, patchy distributions can occur with schooling species. The most abundant marine species include arctic cod, fourhorn sculpin, saffron cod, capelin, several species of snailfish, arctic flounder, and starry founder. Arctic cod has been described as a "key species" of the ARctic Ocean because of its abundance, widespread distribution, and trophic importance to marine mammals, birds, and other fish. Species such as arctic cod and capelin, periodically enter nearshore areas to feed on epifauna or to spawn. Other species, such as fourhorn sculpin, saffron cod, and founder, remain in coastal waters throughout the open-water months and move further offshore during winter months. Spawning by marine fish species occurs nearshore (or offshore) during winter months; however, capelin spawn in late July or early August (BLM, 1979; Craig and Haldorson, 1981; MMS, 1984). Harvesting of marine fish species by subsistence fishermen is traditional in Beaufort Sea coastal communities (e.g., Barrow, Kaktovik). Arctic cod is fished through the ice during late fall and winter while capelin is harvested in July and August (MMS, 1984 ). Project activities are not expected to impact fish resources in the Beaufort Sea since effects will be localized and short-term in nature. No impacts to subsistence or commercial fishing are expected since these activities do not occur at the project location or along routes that project support vessels would utilize. 6.5 Marine Mammals Several species of marine mammals occur in the central Beaufort Sea region. Ringed seals (P_hoc~a hispida) are year-round resi- dents. Bearded seals (Er.i~nathus. barbatus) and spotted seals (Phoca largha) are present during the open-water period, and a -30- very few of the former may overwinter in the Beaufort Sea. During the open-water period, a small number of walrus (O~dobe~nu~s rqsmarus) may also enter the area. Polar bears (Ursqs maritimus) are present near the coast during the winter, but they move north with the ice pack during summer. Bowhead (Balaena mysticetus) and beluga whales (Delphin_apterus leucas) make a far offshore, eastward migration during the spring and a westward return migration in the fall. Gray whales (Eschrichtius robustus), whose normal summer range extends as far north as the Point Barrow area, very occasionally are found as far east as the central Alaskan Beaufort Sea. Non-endangered marine mammal species are discussed below. Bowhead and gray whales are dis- cussed in Section 6.7, Threatened or Endangered Species. Ri nge~d Seal , · The ringed seal is the most abundant marine mammal in the project area. The Beaufort Sea population is estimated at 80,000 ringed seals in the summer and 40,000 during the winter (Frost and Lowry, 1981). Ringed seals do not congregate into large herds; however, loose aggregations of tens and hundreds of animals do occur. Densities within the project area depend on a variety of factors such as food availability, proximity to human distur- bance, water depth, and ice stability. Ringed seals are year-round residents in the Beaufort Sea. In winter and spring the animals are associated with landfast ice or stable pack ice, and the shear zone nearshore. During breakup and the retreat of ice form the coast during the summer, ringed seals concentrate along the ice edge. Some seals may remain behind and more may move into the open water during late summer. Breeding ringed seals overwinter in areas of landfast ice, where they are territorial and maintain breathing holes through the ice. In later March and early April, females give birth to a single pup in lairs hollowed out of snow drifts on the ice -31- surface. The pups are weaned at about six weeks of age. Additional ringed seals, mainly sub-adults and non-breeding adults, are found in the transition zone pack ice seaward of the landfast ice. Ringed seals molt during May, June, and early July. During this time, seals commonly haul out to bask and rest on the ice for long periods of time. Ringed seals feed on a variety of prey depending on season and location. Food items include cod, mysids, amphipods, and euphausids. Important predators of ringed seals include polar bears and arctic foxes. Bearded Seal Bearded seals are abundant in the Bering and Chukchi Seas where an estimated 300,000 to 450,000 individuals exist (Braham et al., 1977). Bearded seals that are present in the Alaskan Beaufort Sea come mainly from the Chukchi Sea. The seals move into the Beaufort Sea during the summer open-water period and nearly all will leave before freeze-up. Adults are associated with the receding ice edge. Juveniles frequent the ice-free nearshore areas. Pupping takes place on top of the ice from late March through April primarily in the Bering and Chukchi Seas. Some pupping does occur in the Beaufort Sea. Bearded seals do not form herds, although loose aggregations of animals do occur. Bearded seals feed primarily on benthic and epibenthic molluscs and crustaceans including isopods, amphipods, clams, and snails. Spotted Segl The spotted seal is a seasonal visitor to the Beaufort Sea. Spotted seals move into the Beaufort Sea from the Chukchi Sea in low numbers (about 1,000). They appear along the coast in July -32- hauling out on beaches, barrier islands, and remote sand bars on the river deltas. The furthest east that spotted seals are regularly found is the Colville River Delta (Eley and Lowry, 1978). They migrate out of the Beaufort Sea in the fall as the shorefast ice reforms and the pack ice advances southward. Walrus The north Pacific walrus population is estimated to be between 170,000 and 250,000 animals. Most of this population is asso- ciated with the moving ice pack year-round. Walrus spend the winter in the Bering Sea and summer in the Chukchi Sea (MMS, 1984). A few walrus move into the Beaufort Sea during the summer open-water season. The majority of the Pacific population occurs west of Barrow, Alaska. Walrus are benthic feeders and rely primarily on bivalve mol- luscs. Other foods include polychaetes, snails, and crustaceans. Beluga Whale The beluga whale is a circumboral species and a summer seasonal visitor to the Beaufort Sea. An estimated 11,500 beluga whales migrate from the Bering Sea into the Beaufort Sea (Davis and Evans, 1982) during.the summer open-water season. They enter the Beaufort Sea at Point Barrow, and from there they follow an almost due easterly course which takes them across the central ice pack to the southeastern Beaufort Sea region (Fraker, 1979). In summer, the beluga whales concentrate in the Mackenzie River estuary. The westward fall migration our of the Beaufort Sea occurs primarily in September. Davis and Evans (1982) showed that the fall migration in the Canadian Beaufort Sea occurred far offshore in 1981. The paucity of sightings of beluga whales near the Alaskan Beaufort coast (Johnson, 1979), despite the large amount of research done there and the large numbers that have been seen offshore, strongly suggests that the majority of belugas migrate far offshore in the fall as they do in the spring. Beluga whales feed on a variety of marine vertebrates and invertebrates such as capelin, cod, herring, squid, and various crustaceans. Pol ar Bear The polar bear is a circumpolar species. The Beaufort Sea population (from Point Barrow to Tuktoyaktuk Peninsula) is estimated to be 2,000 bears (Amstrup, 1983). The total Alaskan polar bear population is about 5,000 to 7,000. There is substantial annual variation in the seasonal distri- bution and local abundance of polar bears in the Alaskan Beaufort Sea. The two most important natural factors affecting distri- bution are sea ice and food availability. Drifting pack ice probably supports greater numbers of polar bears than either shorefast or polar pack ice, due to the abundance and availa- bility of subadult seals in this habitat (Smith, 1980). Except when females den on land, polar bears usually remain on the sea ice. Pack ice normally carries bears north of the Harrison Bay area during summer. During winter, males and sub-adults appear to be more mobile, and move relatively long distances, sometimes into Harrison Bay. Females may den on sea ice, particularly in the ridged ice zone. There is a growing body of information that suggests that many female polar bears dig maternal dens on the sea ice (S. Amstrup, pers. comm. and Lentfer, 1975). Lentfer and Hensel (1980) indicate that histori- cally, some important denning habitat existed in land in and adjacent to the Colville River Delta, but that current use of the area is apparently relatively low. -34- Detailed information on polar bears in the barrier island area is lacking; however, it is known that they tend to be attracted to areas where ringed seals, their principal prey, are abundant. Because seals are not particularly abundant in the project area, polar bears are probably relatively scarce as well. Polar bears off the Alaskan coast feed primarily on ringed seals and to a lesser extent, bearded seals and walrus. The polar bear is an opportunistic feeder occasionally frequently coastal areas to feed on carrion, especially whale carcasses. Bears will also scavenge through human refuse when it is available. Other less common marine mammal species that could occur in the area include the narwal (Monodon nonocerus), killer whale (Or- cinus or.ca) , harbor sea (Phoca vitulina richa~dsi), harp seal · (Phoca gr. oenlandica), hooded seal (Cysto.ph.o..c.a cristata), northern fur seal (Collorhinus ursinus), and northern sea lion (Eume- _ , ~,_ ~ L ,= ,, topias jubata) (Eley and Lowry, 1978). The major effect of the proposed activities on marine mammals will be the .disturbance from noise generated by the project. Sources of noise disturbance will be from over-ice vehicles on the ice road, support vessels, support aircraft, and drilling activity. Mobile airborne sources of noise can disturb hauled-out seals and polar bears occurring within a few kilometers of the source. Seals are possibly more sensitive during molting in the spring. Polar bears can be especially sensitive to noise during maternity denning; however, preliminary results of noise measurements taken within a simulated polar bear den suggest that noise would only be detected by denning bears if the sources was very near the den. Mobile sources of underwater noise primarily include support vessels, support aircraft, and drilling equipment. Fraker e.t a__l. (1981) reported that composite sounds from island construction activities from an artificial island were above ambient levels at a distance 4.6 kilometers (2.9 miles) north of the island. Malme and Mlawski (1979) recorded noise from drilling rigs on a natural and artificial island in shallow water (1-12 m) (3.3 to 39.4 ft) near Prudhoe Bay during ice cover. Low frequency sounds were still recorded at a distance of 6.4 to 9.6 kilometers (4.0 to 6.0 miles) from the drilling area under quiet ambient noise con- ditions, although this disturbance was decreased to 1.6 kil- ometers (1.0 mile) under noisy ambient levels. Underwater sound propagation loss is higher in shallow water than in deep water. Underwater noise may affect marine mammals by disturbing or alarming the animals and causing them to flee the sound source. Underwater noise may interfere with or mask reception of marine mammal communication or echo-location signals. Noise may also interfere with the reception of other environmental sounds used by marine mammals for navigation. Frequent and/or intense noise that causes a flight or avoidance response in marine mammals could displace animals from important habitat areas. However, the monitoring of beluga whale behavior and distribution for the past 10 years in the Mackenzie River Delta estuary in association with marine traffic supporting Canadian oil and gas activities has not shown long-term or permanent displacement of whales from a portion of the estuary with comparatively high levels of indus- trial activity. Due to the low levels of underwater and airborne noise, timing of drilling activities, and the relatively short duration of project activities no long-term displacement or disturbance of marine mammals is expected. -36- 6.6 Coastal and Marine Birds ~ _ Several million birds, consisting of about 150 species of sea-birds, waterfowl, shorebirds, passerines, and raptors (including the endangered peregrine falcon, discussed in Section 7.7) occur on the North Slope (Pitelka, as cited by Schamel, 1978). The great majority of birds in the area are migratory. Only six species are present from September to May. These overwintering species are rock ptarmigan, willow ptarmigan, snowy owl, common raven, gyrfalcon, and black guillemot (BLM, 1979). The most abundant marine and coastal species include: red phalarope, oldsquaw, glacuous gull, common eider, king eider, spectacled eider, arctic tern, arctic loon, red-throated loon, yellow-billed loon, pintail, white-fronted goose, black brandt, Canada goose, lesser snow goose, whistling swan, pectoral sandpiper, dunlin, northern phalarope, semipalmated sandpiper, parasitic jaeger, pomarine jaeger, longtailed jaeger, Sabine's gull, Ross' gull, ivory gull, and blacklegged kittiwake (MMS, 1 984 ). Major concentrations of birds occur in nearshore (water less than 20 m [65 ft] deep) and coastal areas such as Simpson Lagoon (MMS, 1984). Spring migration to the North Slope and western Beaufort Sea occurs from mid-May to June 20 (Richardson and Johnson, 1981 ). Coastal and offshore migration routes are greatly influenced by spring ice conditions; timing is influenced by wind direction and availability of open-water leads (Divoky, 1983). After arrival in the spring, most shorebirds and waterfowl disperse to nesting grounds located primarily on moist tundra and marshlands of the arctic slope. Species such as common eiders, arctic terns, glaucous gulls, and black guillemots nest on barrier islands. Timing of ice breakup surrounding a barrier island is critical for determining its importance as a marine bird nesting site. For this reason, islands near large river deltas receive the heaviest use (Divoky, 1978). Cross and Egg Islands near Prudhoe Bay support small groups of several species (Divoky, 1978). MMS (1984) notes that the number of nests on these islands is low compared to the overall bird resources of the arctic slope, but these sites are considered more important than other barrier islands where nesting does not occur. Figure 6 shows locations of bird colonies or nesting sites (less than 10,000 individuals per colony) in the vicinity of the project site. Beginning in mid-July, large concentrations of 10,000 or more oldsquaw occur in coastal waters inshore of islands (e.g., Simpson Lagoon) where they feed intensively and molt prior to fall migration. In late July, phalaropes and shorebirds also concentrate along the coast, feeding intensively at coastal beach habitats of barrier islands and along lagoon coastlines, marsh- lands, and mudflats (Conners et al., 1981). Fall migration in late August and September is focused along the coast with molting and staging occurring in lagoons, coastal tundra lakes, ponds, and river deltas (MMS, 1984). Figure 6 shows highly sensitive coastal bird habitat (i.e., major feeding and/or molting concen- tration areas) in the vicinity of the project site. Beaufort Sea avian species include both offshore and nearshore feeders. Offshore feeders such as arctic terns and black guillemots feed primarily on fish, especially arctic cod. Near-shore coastal feeders prey on various invertebrates and emergent vegetation. Sea ducks (e.g., oldsquaw) feed on benthic crustaceans, particularly mysids. Other waterfowl, and shorebirds feed on various adult and larval insects, crustaceans, and molluscs inhabiting coastal salt marshes and tundra ponds (Connors et al., 1981 ). , -- Although project activities may occur while bird populations are utilizing adjacent coastal areas, there will be no significant impact from the project or its support vessels. Support services -38- I ! ! J ! ! ! J ! ! J J J J ! ! ] 'J ] B E A U F R BARRIER ISLAND NESTING SITES MOLTING 8, NEARSHORE FEEDING CONCENTRATIONS T NORTHSTAR NO. 3 BAY 15 0 15 30 k-'----I I I I I SCALE IN MILES Figure 6 Location of Bird Colonies and Nesting Sites in vicinity of Project Area. for the project will be based in the Deadhorse/Prudhoe Bay area. There will be no use of the adjacent barrier islands nor will crew members be allowed access to the islands for other than work related activities. Project activities are not expected to interfere with bird migration or flight patterns and no impact to the bird population is expected as a result of the project activities. 6.7 Threatened or Endangered Sp_eci_es There are two mammal species listed as endangered by the U.S. Fish & Wildlife Service that occur in the general project area. They are the bowhead whale (Balaena mysticetus) and the gray whale (Eschrichtius robustus). One bird species, the arctic peregrine falcon (Falco peregrinus tundrius) listed by the U.S. Fish & Wildlife Service as threatened and by the State of Alaska Department of Fish & Game as endangered, may also occur in the general project area. No other federal or State of Alaska listed threatened or endangered animal or plant species are found in the project area. Bowhead Whale The bowhead is a large ice-associated baleen whale that inhabits Arctic waters. Only a few years ago, it was thought that the Western Arctic bowhead stock might have contained fewer than 1,000 individuals, but recent more accurate estimates have resulted in a much brighter picture. The Scientific Committee of the International Whaling Commission (IWC) has accepted 3,871 (+254) as the current "best estimate" of the size of this stock (IWC, in press). Davis et_ ~al. (1982) arrived at an independent estimate of 3,842 for the surveyed area on t~he summer feeding grounds on the eastern Bering Sea. Recent research by Clark (1983) indicated that many whales are undetected in the routine annual census at Barrow, and that current estimates may be low by 15 to 40 percent. -40- Bowheads winter in the Bering Sea and summer in the Canadian Beaufort Sea. Beginning in late March and early April, bowheads start to move north in the Bering Sea, passing through the Bering Straits to enter the Chukchi Sea. From mid-April to early June they migrate through the coastal leads along the northwest Alaskan coast to Point Barrow (Krogman et a1.,1982). From Point Barrow, the whales move east and northeast through the offshore pack ice (Braham et al., 1980; Ljungblad, 1981; Ljungblad et al., 1980). The summer feeding range of the bowhead is mainly in the Canadian Beaufort Sea (Fraker and Bockstoce, 1980). The whales begin their activities on the eastern and northern parts of their summer range, and during the course of the summer the whales shift westward, with the first whales entering the eastern Alaskan Beaufort Sea in August or September (Ljungblad et al., 1983). The westward fall migration begins sometime after mid-September and continues into October. The data from 1979 to 1982 show that the vast majority of sightings have been in waters of 18 m to 20 m or deeper, and that the whales migrate across a broad front extending seaward to at least the 50 m isobath (Figure 7). Limited data suggest that some whales migrate even further offshore. The closest sighting of whales to the project area is approximately 11 km (7 mi) to the north. Bowheads have been reported to feed at certain locations in the Alaskan Beaufort (Braham and Krogram, 1977; Ljungblad et al., 1980, 1983; Lowry and Burns, 1980), particularly in the area just east of Kaktovik. Kaktovik is near the western extremity of the main feeding range, which lies mainly in Canadian waters (Fraker and Bockstoce, 1980). Outside of the area near Kaktovik, feeding in the Alaskan Beaufort is not predictable. Bowheads may feed anywhere that food is available in sufficient concentrations to make a feeding effort worthwhile. There have been scattered observations of "possible feeding" made in the Alaskan Beaufort ! .. .... '--. ...... ., ,,, ,, ,'-- ,- ..::~:_'.;. ~o0 ..'-~ ............ . , , I I *- '~ '-;-~-'-.'-;-=- =::-=-- ,= ...... === ............ :---:---.':-.'-:-;--- -- ,, 'J · ........ ............ o __ ', ':.. ..... = ..... ""- _-= ........ =:::::: ..... ~---~-~':~.'-~--~- .... ..'. ,* - ":-~"::~- - - ~00'.'-~< ...... = ....... I .... J s .~ ''-;::::-JO0-- ''--::'';::~=: ........ :==:::;:::::Z:-.;-;--;.-'-_ .... ''~ ' 'I I ........~:~.. '- - - -o- - - -. ............ '. ' ' - - ';~;:';:'::-. '1- - ~ 1 ;. L "---:-,, '-.. ',,' 1 -I~.zo~__ . > -, .... - I ! -. o ~ o · , . ', '., '. , ~2 ',o ~ -.._:-o 1 ~~ "".. .... . ................ : .... T?_STAR .o. ~1 ,: d~t o G nC~'Z~ .~e ~- ~n / ~ ~_1~ ~.'~ DEPTH IN METERS v~ l~ g ) ,,' ........ Figure 7 Locations of bowhead whale sightings in the project area during September and October of ]979 through ]982.' Sea (D.K. Ljungblad, pers. comm.; Ljungblad et al., 1983). However, the distribution of food organisms is patchy and highly variable in these regions (Horner et al., 1974). The preferred foods for bowhead whales are pelagic arthropods such as euphausiids, mysids, copepods, and amphipods. Gray Whale The gray whale is a benthic feeding baleen whale occurring only in the North Pacific and adjacent waters of the Arctic Ocean. In the summer, gray whales range primarily in the Bering, Chukchi, and Western Beaufort Seas. Current population estimates place the gray whale at roughly 16,000 whales. The species may be approaching or may have exceeded pre-exploitation levels of abundance. The gray whales endangered status is currently under review and declassification is likely. There is a small but apparently regular movement of gray whales into the Western Beaufort Sea during the summer open-water period. Thirteen gray whales were landed by the Eskimos from Barrow in the 30 year period from 1950-80; a single animal was taken at Cross Island, east of Harrison Bay, in 1933 (Marquette and Braham, 1982). Three gray whales were sighted in the Canadian Beaufort ~Sea in 1980 (Rugh and Fraker, 1981). It is possible that a few gray whales might be present in the project area during the summer. Ar~ctiq .peregr ine Falcon The arctic peregrine falcon occurs in the Beaufort Sea area each year during late summer to early fall (mid-August to early September) as they migrate from nesting areas in the foothills of the Brooks Range down the Colville River to the outer coast. The falcons then fly eastward into Canada where they are thought to migrate south along the Mackenzie Valley to wintering areas further south. On some occasions during this autumn migration, arctic peregrines may linger at some coastal locations where they hunt waterfowl and shorebirds. 6.8 E_ffects of Pr_oposed ~Acti_vitie~s Bowhead whales have been shown to be sensitive to noise generated by low flying aircraft. However, aircraft (fixed-wing) flying at 305 meters above sea level or higher appears to have little or no discernible effect on bowheads (Davis and Koski, 1980). Nearby boat activity also affects bowheads. Bowhead whales tend to move away from vessels which approach within one kilometer and have been known to react to boats as far away as 3.7 kilometers. In general, bowhead flight responses are somewhat tolerant of ongoing noise from boats and may habituate to continuous boat so u nd s. Drilling noise may be less disturbing to bowheads than boat noise. Richardson e~t aI. (1983) reported seeing bowheads as close as four kilometers from an operating drillship and industry personnel report even closer sightings (MMS, 1984). There are no consistent indications of unusual behavior among whales observed within 20 kilometers of drillships. Fraker et al. (198.1) frequently observed bowheads quite close to island construction sites during the summer months. The bowhead may habituate itself to the noises associated with island construction. Once in place, it is unlikely that temporary artificial islands will interfere with bowhead whale migration or other behavior (MMS, 1984). The proposed exploratory drilling activity will have a negligible impact on the Western Arctic bowhead stock. No measurable short-term or local change in numbers or distribution of indivi- duals is expected as a result of the project. The majority of activities will take place during the winter and summer when -44- bowheads are not present in the project area. Ail support traffic will be kept to a minimum and will follow the most direct routes to and from the drilling vessel and Deadhorse/Prudhoe Bay. Support aircraft will maintain a minimum altitude of 457 m (1 500 ft) when in flight to or from the project area. Ail drilling and other downhole activities will be undertaken in full compliance with the State of Alaska's Department of Natural Resources and Environmental Conservation Commissioner's decision of May 15, 1984. The proposed exploratory drilling activities are unlikely to have any significant effect on gray whales migrating through the Beaufort Sea. Very few, if any gray whales could be expected to be present in the area during the life of the project. The proposed exploratory drilling activities are not likely to have any significant effect on Arctic peregrine falcons. 7.0 PROPOSED DEVELOPMENT SCENARIO (Figure 8) On site project activities will begin in late July or early August, 1987 with detailed bathymetric and side scan surveys of the proposed site. Any deep ice gouges or other anomalous bottom features will be further investigated by divers. Following data analysis, the results of these surveys will be presented to the Alaska Oil and Gas Conservation Commission (AOGCC) and Department of Natural Resources (DNR). The Global Marine Concrete Island Drilling System (CIDS) "GLOMAR BEAUFORT SEA I" will be employed to drill the Northstar No. 3 well, and any subsequent wells from the same location. This drilling unit is currently stacked approximately 6 miles east of the proposed location. In mid-August, 1987 the rig will be de-ballasted and floated to the proposed location. The vessel will be towed by three (3) 9,000 hp (7,200 bollard hp) class I PERMIT ACQUISITION 2 ADDITIONAL SITE SURVEYS 3 MOBILIZE ClDS BEAUFORT SEA I 4 DRILL TEST. P&A NORTHSTAR NO. 3 (STRAIGHT HOLE) 5 BOWHEAD WHALE FALL MIGRATION 6 DRILL, TEST. P&A. NORTHSTAR NO. 4 (DIRECTIONAL HOLE) 7 POSSIBLE ICE ROAD CONSTRUCTION 8 DRILL, TEST. P&A, NORTHSTAR NO. 5 (DIRECTIONAL HOLE) 9 RIG RE-SUPPLY (AS REQUIRED) 10 DEMOBILIZATION 1987 1988 JUL AUG SEP OCT NOV DEC JAN FEB MAR APR MAY JUN JUL AUG III II IIl~~lll IIII IIIIIIIIIIIII IIIII JUL AUG SEP OCT NOV DEC JAN FEB MAR APR MAY JUN JUL AUG , Northstar No. 3 SCHEDULE OF ACTIVITIES I FIGURE ocean going tugs. The tugs will be in the Beaufort Sea/Prudhoe Bay vicinity as part of the 1987 sealift of production modules to Endicott. The drilling site will have been previously marked with buoys during the marine survey phase of the project, and mobilization will be timed to coordinate a favorable weather window and tug availability. The vessel will be positioned on site using electronic position- ing equipment. Ballasting operations will result in gravity load on the seafloor sufficient to resist ice pressures which will develop during the winter. An inspection dive may be made following ballasting to assess mud skirt penetration and general seabed conditions with the rig in position. Supplies of fuel, mud materials, cement, casing, wellhead equipment and other materials as required will be put aboard the , rig from a supply barge operating out of West Dock at Prudhoe Bay. The consumable capacitY of the CIDS is sufficient for up to four months of operation and major resupply will not be required until well into the winter months. Sufficient casing and other tangible equipment for two (2) wells will be loaded at this time. Personnel, grOceries and miscellaneous materials will be trans- ported on an as-needed basis by helicopter from Deadhorse. Approximately 35 days will be required to drill the Northstar No. 3 well to 11 ,350 ft TVD. Testing will consume an additional 25 or more days, depending on the amount of reservoir evaluation required (Figure 8). An additional 5 days are programed for plugging and abandonment. The possible second and third wells (Northstar No's 4 and 5) are programed as directional holes and will require approximately 85 to 90 days each to drill, test and P & A. -47- Northstar No. 3, as well as any subsequent wells will be ex- pendable wells regardless of any commerciality demonstrated during testing. The wells will be abandoned in accordance with Alaska Oil and Gas Conservation Commission regulations. In February and March of 1988, an ice road may be constructed to the location from West Dock. This road would be used to resupply the CIDS with fuel and other materials to continue operations into late spring. Following the completion of drilling and testing operations and release of the rig by AHC, the CIDS will remain on location until the open water season. At this time, it may be deballasted and floated to a new location. Lacking a contract for additional work, the vessel may remain stacked at the Northstar No. 3 location. If the vessel is to remain on location, permits will be obtained for this activity. 8.0 DRILLING VESSEL DESCRIPTION (Figure 9) The Glomar Beaufort Sea I, Concrete Island Drilling System (CIDS) will be used to drill the Northstar No. 3 well and any subsequent wells from the same location. The CIDS is a bottom founded modular concrete structure which supports a barge mounted drilling rig, camp and other facilities. The modules incorporate an efficient honeycomb structural system that provides great longitudinal, transverse and torsional strength. This structural design is based on-a "brute mass" approach that obtains sufficient gravity load on the seafloor by ballasting with seawater and relies on passive crushing of the local ice sheet. No active ice defense mechanisms are required. When fully ballasted with seawater the structure provides both a sufficient gravity load to hold the CIDS on location when exposed to ice loads up to 460 kips/ft, as well as adequate freeboard to -48- Figure 9 CONCEPTUAL RENDERING OF CIDS RIG -49- keep the deck dry during summer storms. Movable concrete armor panels are placed at the ice line to transmit highly localized ice forces into the hull structure. The deck barges provide sufficient storage capacity, and deck space to support up to four months of operation without major resupply. Following the completion of operations the CIDS can be deballasted, floated and towed to a new locaiton. The CIDS GLOMAR BEAUFORT SEA I which has been contracted for the work described herein has previously been used successfully by Exxon in the Cape Hallket area through two complete ice season. 8.1 Marine Sp.eci. f_~icatiqns Classification: ABS Maltese Cross A-1 Caisson Drilling Unit . County of Regist. ry: USA Operating_ Param..eters: Maximum water depth: Minimum water depth: Minimum temperature (operate): Structural Design Ice Load: (diagonal width) Ice Control Pressure: Principal. Dimensions: Deck: Length Over all Breadth Base: Length Over all Breadth Depth From Deck to Baseline: Loading and Towing Data: Average Towing Speed: (ocean transport) 50 ft. 35 ft. -60 °F 460 kips/ft 900 psi (5'x28'area) 290.5 Feet 274 Feet 312.5 Feet 295 Feet 95 feet 4.0 knots with Two (2) 22,000 IHP Oceangoing Tugs -50- Minimum Draft: Capacities: Drill Water: Potable Water: Fuel Oil: Bulk Cement: Bulk Mud: Liquid Mud: Reserve Tanks Tubular Storage Area Sack Storage: Mud & Cuttings Storage: He..1 ipor~t: 73 feet x helicopter fications. Perimeter amber lights. One (1) Mission fugal, 900 gpm. 24 Feet skirts 29 Feet skirts (approx.): without mud with mud Cement 34,736 bbl 730 bbl 48,712 bbl 9,000 cu ft 27,000 cu ft 2,750 BBL 4,050 sq ft. (enclosed) plus additional outside storage 2,000 sacks open. area (not enclosed) 4,000 BBL 73 feet. Designed to support an S-61N in accordance with U.S. Coast Guard speci- lighting system with alternating blue and Helicopter fire foam pump, centri- One (1) National gallon tank with operating heads. Four (4) National Foam hose stations, 50 ft. live hose reel w/PC-12 nozzles. Fireman outfit Helicopter rescue equipment per Foam PPH 60 foam proportioner, 175 1-1/2 inch hose, USCG requirements. Quarters: Quarters for 83 men Hospital quarters for 7 men Galley and mess room Recreation room M~et~9orplogical Instrumentation: One (1) Bendix-Friez anemometer One (1) OSI barometer One (2) OS I thermometer One (1) OSI hygrometer One (1) OSI precipitation indicator Ice Forces Instrumentation: Ailtech, stress/strain sensor system OSI concrete wall ice force stress panel monitoring system Two (2) Validyne embedment strain gauge readout panel N.a.v i.g at.~On _~qu i~Pmen t~: Two (2) Kokoska, side lights. One (1) Kokoska, stern light One (1) navigational lighting panel Two (2) Carlisle & Finch, search lights One (1) portable signaling light Four (4) obstruction lights, Automatic Power One (1) fog signal system, 2 mile range, Automatic Power Communications Equ. ipm~ent: One (1) Texas Instruments single side band radio telephone with antenna Two (2) Texas Instruments VHF marine radio telephones with antennas -52- One (1) VHF - AM radio telephone with antenna for helicopter communications One (1) helicopter homing beacon Ten (10) Atkinson Dynamics listen/talk amplified PA system Nippon Hakuyo dial telephone system Hose - McCann 1 JV sound powered telephone system E- call sound powered telephone system Moor ing LSyste_m: Two-point anchor system Moorings: Two (2) 3,000 foot x 2-1/4 inch, 6 x 37 IPS, IWRC wire lines Two (2) 20,000 lb anchors Mooring Winches: One (1) Double drum, DTW-150 Skagit winch driven by a diesel engine. Two (2) Amco Model 750 single drum winches. Marker buoys on location Four (4) anchor buoys Pendant wires, shackles and associated jewelry Workboat Mooring Line Power Generation: Three (3) Caterpillar, D379 diesels with Kato gener- ators, 1,200 rpm, 400 KW generators at 0.8 PF, 480 VAC, 3 phase, 60 Hz. One (1) Kato emergency generator driven by Caterpillar D379 diesel, 1,200 rpm, 400 KW at 0.8 PF, 480 VAC, 3 phase, 60 Hz. Distribution switchboard, AC. Two (2) Torishima stepdown transformers, 1000 KVA- Delta Wye, 480 VAC to 208/120 VAC. Two (2) each Pump room motor control centers. Emergency switchboard. One (1) Torishima emergency stepdown transformer, 75 KVA-Delta Wye, 480 VAC to 208/120 VAC. One (1) emergency quarters generator. A. ir .Compress. ors.: Two (2) 60.2 CFM, 125 psi air compressors, electric One (1) 17.2 CFM, 125 psi air compressor, diesel Fresh Water Supply Equipment: One (1) 15,000 gal/day rated reverse osmosis Three (3) 2,400 gal/day rated waste heat distillers. Fi~r~efighting and Sa,fety..E~uipmen~t: Kidde Halon fire extinguishing system in engine room, paint locker, emergency generator room, and water cannon pump house. Deluge system Portable dry chemical fire extinguishers Portable CO2 fire extinguishers Smoke detector installed in each crew accommodation Lifesavi. ng E~u..ip. ment: Life Rafts: Sufficient USCG approved inflatable life rafts to accommodate all personnel onboard suitable for Arctic service. Two (2) Whittaker arctic survival capsules, 54-man, USCG approved, with launch system. Life Jackets: Sufficient to furnish all personnel with one (1) each plus excess as required by USCG. Life buoys: Eight (8), Cal June Work vests: Twenty-five (25) USCG approved, stearns. Medical Facilities: First Aid supplies and equipment. Hospital with seven (7) berths Stretcher, Marine Safety -54- Reserve Mud System: One (1) Mission, reserve pit transfer pump, 6 x 8, 100 psi discharge, driven by 100 HP motor. Four (4) Brandt, reserve pit agitators, 25 HP each. Bulk System: Twelve (12) bulk storage tanks, 3,000 CF capacity, 12 foot diameter x 32 feet high, 40 psi operating pres- sure. One (1) tank to have weighting scales. One (1) blend tank, 500 CF capacity, 40 psi operating pressure with weighting scales. Two (2) dust collectors One (1) transfer air compressor, 450 cfm at 40 psi, diesel powered One (1) dry additive system for filling bulk storage tanks with sack material Cranes and Loaders: One (1) Crawler Crane with 120 foot boom rated at 100 tons One (1) Wheeled Crane with 91 foot extended boom rated at 18 tons American pedestal crane with 140 foot boom rated at 100 tons One (1) caterpillar 966-C front end loader with bucket and two (2) forks W.e.!~ding Equipment: One (1) 400-amp Lincoln electric unit One (1) 300-amp portable diesel electric unit L~iq.h.ti~ng,~ Wiring, and Controls: Vapor-proof or explosion-proof, as required by USCG regulations Sewg. ge- Treatment Plant: USCG approved sewage collection and treatment system certified to accommodate 100 persons ° .Spe~cial Servi_ce_s and ..E~quipme~nt: Cementing Unit: Cementing unit with two (2) diesel engines ° ._Well Testing.._Flar..e Equipment: (1) Two (2) each flare booms for well testing (2) Manifolding and piping as required to end of boom for gas (3) Test separators, including burner 8.2 Dr~.illing Rig .Speqifications The drilling rig to be used for the proposed exploratory drilling operations will be Parker Drilling Company Rig No. 217. This rig is currently aboard the GLOMAR BEAUFORT SEA I. Depth Rating and General Description: Diesel-electric SCR Drilling Rig rated to 25,000 ft. Rig is designed and winterized to operate in arctic environments. Drawworks: One (1) OIME Model 2000E Drawworks complete with Baylor-Elmagco model 7838 electric auxilliary brake, 1-1/2" lebus grooving, drum size 32" diameter by 56" wide x 58" x 12" hard-faced brake rims, and type K drum brake linkage, fully equalized. Drum drive chains 2" pitch quadruple, transmission chain 1-3/4" pitch sextuple, high drum clutch- Twin Disc PO 336 and low drum clutch - Twin Disc PO 342. Foster 37AH and 24 AH air actuated catheads, rotary drive assembly using Twin Disc PO 318 clutch, and Duomatic crown block protector. Mast and Substructure: Parco, type Cantilever, static hookload capacity 1,250,000 l~b strung with 12 lines, 650,000 lb set back capacity, racking platform capacity 25,000' of 5" drill pipe. Leveling shims and jack. Removable/adjustable stabbing board. Height of rig -56- floor wind break: 60 ft. Height of derrickman wind break: 15 ft. Parco substructure, 34 ft high, 30 ft beneath rotary beams. Rotary; Table: 37-1/2" Oilwell rotary table with 650 ton load capacity. Traveling E_qu_ipmen~t: Ideco, and Ideco 525 ton hook. 525 ton, with 6 sheaves Crown Block: Parco crown block, grooved for 1-1/2" . -- line, 60" sheaves with 72" fast line sheave with sand line, cat line, and tugger line sheaves. Capacity 650 tons. Crown-O-Matic: Duo-matic crown block installed Rotary Hose:~ One 3-1/2" ID X 60' , 5000 psi working pressure with 4" connections. Prime Movers: Four (4) Caterpillar Model D-399 turbo charged after-cooled engines. Rated at 1000 HP con- tinuous at 1200 RPM. Four (4) Kato brushless generators, 1050 KW. Six (6) EMD79-MB drilling motors complete with quick- disconnect junction box, explosion proof lockout device, high capacity 7.5 hp blower, and Hunt air cure vents. One (1) Ross Hill SCR Controls package completely housed with four (4) model 1201 SCR drive cubicles with bridge rated at 1600 AMPS. Cubicles are complete with AC alternator control section for alternators including AC control module ( electronic-governor-voltage- -57- regulator) and power limit; one (1) model 1201 SCR drive cubicle, one (1) 1600 amps feeder breaker for the 600 volt distribution section; driller's console, driller's foot throttle; 225 KVA, 600/480 ~volt domestic type core and core transformer in NEMA III enclosure. Mud System: · Mud Pumps: Two (2) National 12-P-160 Triplex pumps, 1600 HP with pulsation and suction dampers, powered by four (4) EMD-79 1000 HP motors. Active tanks, compartmented with sand trap, slugging pit, with 1,100 BBL volume. Dual tandem Brandt shakers mounted on sand trap. Two (2) Brandt SRS-2, 2 cone desanders at 1,000 gallon each, mounted over a single screen shale shaker for closed system operations. Two (2) Brandt mud cleaners or equivalent, capable of 400 GPM each. Mud Agitators: (1) Each mud pit has individual bottom mud guns. (2) Each mud pit has individual agitators, Brandt MA 7.5 - 7.5 HP. OIME Mud Gas Separator: Two Centrifuges, equivalent to Pioneer Mark I. -58- Degasser: Swaco, capable of handling 1,000 GPM with independent pump and explosion-proof motor. Mud Testing Facilities: Baroid Offshore test kit. Two mud mixing pumps driven 100HP electric motors. 5" x 6" x 11" Mission Magnum. Gas Detection System: Fixed combustible four-point monitor gas detection system complete with control modules, general alarms and sensors; one each sensor located at central ventilation inlet for air ducts, on bell nipple, shaker-pits and on drill floor to comply with regula- tory requirements. Drill String: Drill Pipe: (1) 16,000' 5" OD, 19.5 lbs/ft. Range 2 grade E and G able to maintain 100,0009 overpull. (2) 1085~ 5" OD, hevi-wate drill pipe. (3) Two pup joints, 5" OD X 5'. (4') Two pup joints, 5" OD X 10' (5) 3-1/2" drill pipe, 10,000 ft. -59- Drill Collars: (1) 18 - 8" OD zip grooved with stress relief grooved in box and pin. 6-5/8" reg connections. (2) 18 - 6-1/2" OD zip grooved with stress relief grooved in box and pin. 4-1/2" XH connections. (3) Crossover subs, bit subs, ×O subs and handling subs to fit all drill pipe and drill collars, and fishing tools. Dr~i!1 st_King Handling Tools: · Drill Pipe Slips: Two (2) sets Varco SDXL drill pipe slips, one set air operated Varco PS15 slips with accessories. Drill Collar Slips: Two (2) sets for 6 1/2" drill collars, Two (2) sets for 8" drill collars. Drill Pipe Elevators: Two (2) sets BJ GC 350 ton 5". Zip Lift Elevators. Elevator Links: One (1) set 2-3/4" X 132" 350 ton links, One (1) set 3-1/2" X 144" 500 ton links. Drill Pipe Tongs: Wooleys super B with lug jaws and hinge jaw spares. Drill Collar Safety Clamps. Two (2) 5KUL Ingersol Rand Air Tuggers with 5000~ pull. -60- C~a~sing and Related Tool_s: Master casing bushings with split type insert bowls for 20", 13-3/8", 9-5/8", and --0I1 . Air impactor wrench with adjustable torque to fit all nuts on well heads and BOP's. Rig Floor .Equipment~: Drillers Console with the following Gauges and Instruments. Weight Indicator - Martin Decker - Hercules Type "E" Pump Pressure Gauge - Cameron - Type "E" Rotary Torque Gauge (AMPS) Pump Strokes Gauges (for Main Mud Pump) Rotary Tong Torque Gauge Martin Decker 7 Pin Recorder Kelly: 5-1/4" Hex X 46 foot, 6-5/8" LHR box X 4-1/2" IF pin Kelly Spinner: International Tool, Model A-6C Wire Line Survey: Mathey electric drive surveyor II with 15 HP motor with 20,000' .092" steel line with circulation head and stuffing box. Iron roughneck, Model 2000 "Big Foot". Automatic Driller: Bear Industries Air Compressors: Two electric screw Gardner Denver BESG. Heating Units: Two (2) Tioga 4,2000 BTU/HR. Flo-Sho on flow line with alarm with recorder. Pit level indicators on all active tanks with totali- zers and recorders at drilling position. Totco Drift Indicator, 0-8 degrees and 0-16 degrees for Subcontractor-furnished equipment. Mud Bucket and Drain. Tong-Torque indicator on each set of tongs. Drill pipe lay down machine with manual back-up operation provided. Blowgut preve_ntion Eqqi~pmen~t: Diverter System: (1) One (1) - 21-1/4" 2000 psi WP annular diverter with spare element on location. (2) One (1) - 21-1/4" 2000 psi WP drilling spool with two 10" outlets. (3) Two (2) 300 psi WP hydraulically operated diverter ball valves. (4) Two (2) 10" diverter lines. 13-5/8" X 10,000 psi WP blowout preventer system: (1) One single 13-5/8" X 10,000 psi type U Cameron blowout preventer with H2S trim. -62- (2) One double 13-5/8" X 10,000 psi Type U Cameron blowout preventer with H2S trim. (3) One double 13-5/8" X 5,000 psi Cameron Type "D" annular preventer with companion flange to bell nipple. (4) Blowout preventers are certified for H2S. (5) Blowout preventer handling system. (6) Drilling spool - 13-5/8" X 10,000 psi WP. (7) Drill pipe test joints. (8) Ram blocks - 3 sets 3-1/2" X 10,000 psi 3 sets 5" x 10,000 psi 2 sets blinds (9) Annular Element: One spare. BOP Choke and Kill Line System: (1) Kill Line: Two 3-1/16" X 10,000 psi full opening gate valves. One 3-1/16" X 10,000 psi check valve. (2) Choke Line: One 3-1/16" X 10,000 psi hydraulic full opening gate valve. One 3-1/16" X 10,000 psi full opening gate valve. (H2S certified) Blowout Preventer Control System: NL Sheaffer 3000 psi accumulator, Model 2016035 with electric hydraulic Tri-Plex pump, two air operated hydraulic pumps, hydraulic pump control panel on drill floor, one removed from drill floor and proper mani- folding valves and regulators for functioning BOP's, HCR valve, d iverter control. Choke Manifold: 10,000 psi WP, H2S trim with two (2) 3-1/16" hydraulic chokes with remote panels, on (1) manual adjustable choke, full control opening 4" bypass. Spare parts for rubber components of BOP system. 13-5/8" X 10,000 Type U casing and tubing rams for 9-5/8", 7" and 3-1/2" pipe. Power trip tank with two 40 BBL minimum compartments. BOP Test Pump: 10,000 psi Tri-plex. Fishi_.ng~ Tools: Overshots, packoffs, extensions and grapples to fish Contractor's drill pipe and drill collars. One (1) 10-3/4" OD full strength series "150" Bowen releasing and circulating overshot with complete accessories to include packoffs, extensions and grapples. -64- One (1) 8-1/8" OD full strength series "150" Bowen releasing and circulating overshot with complete accessories to include packoffs, extensions and grapples. Taper taps with proper OD's to fit ID's of drill pipe and drill collars. One 8" OD X 20" stroke Bowen fishing bumper sub, with 3-1/2" ID circulating hole. One 6-1/2" OD X 20" stroke Bowen fishing bumper sub, with 2-1/4" ID circulation hole. qownhole Tools and Equipment: casing protectors: Antelope. 324 ea 7-1/4" X 5" Bettis Control Valves: (1) Two (2) full opening safety valves for Kelly equivalent to Omsco lock open type, upper kelly cocks, 10,000 psi WP. (2) One (1) test safety valve for 5 inch drill string equivalent to TIW type, lower kelly valves, 10,000 psi WP. (3) Two (2) test drill pipe safety valves for 5 inch drill string with crossover subs to each connection in drill string. -65- (4) Two (2) inside blowout preventers for 5 inch drill pipe, Gray Took Company or equivalent, 10,000 psi WP with crossover subs to each connection in drill string. Float Valve: Two (2) full-flow drill string to fit subs as fol lows: 7-5/8" API Regular 6-5/8" API Regular 4-1/2" API Regular 8 3 Wastewater Cuttings, and Drilling Fluids Disposal The GLOMAR BEAUFORT SEA I has three suitable methods for the disposal of non-oily waste fluids and cuttings: (1) Overboard discharge diluted with seawater, 10:1 minimum (2) Overboard discharge of undiluted cuttings (3) Storage in holds of CIDS for later disposal Wastewater, as well as non-oily muds and cuttings from the proposed operation will be disposed of into the Beaufort Sea in accordance with the terms and conditions of the U.S. Environ- mental Protection Agency (EPA), Beaufort Sea General NPDES permit. Application for coverage under the General Permit has been made by Amerada Hess Corporation. Table 3 shows the estimated quantities of waste materials generated from the Northstar No. 3 exploratory well. Raw sewage will be treated in USCG approved marine sewage treatent unit. This equipment is a biological activation unit utilizing extended aeration and chlorination. Following treatment effluent and sludge will be discharged. -66- J ! ! J ! ! ! ! ! ! i ! ! I ! ! ! ] J Table 3 Estimated Quantities of Waste Materials Generated from Northstar No. 3 Exploratory Well. (Based on 65 Day Drill lng and Testing Program) WASTE QUANT I T I ES Per Day Per Well Disposal I I Drl II lng Mud 15 bbl 3,550 bbl Cuttlngs 25 bbl Sewage and Gray Water Trash-Combustible materials - wood boxes, paper, kitchen wastes, etc. Junk-Noncombustlble Items, such as oil drums, junk metal, tires, batteries, etc. 4,250 bbl 4,000 gal 280,000 gal 1,000 lb 70,000 lbs 500 - 1,000 lb 85,000-170,000 Discharge Into Beaufort Sea In accord with general NPDES permit. If oll contaminated, mud will be InJected Into subsurface dlsposa I zone or transported to approved onshore dlsposal site. Discharge Into Beaufort Sea In accord wlth general I~°DES permit. Any oll contaminated cuttings will be transported to an approved onshore dlsposal site. Discharge Into Beaufort Sea in accord w lth general I~=DES perm It. Incinerate at site. Transport to an approved onshore disposal slte. 1 Includes approximately 1,000 bbl of mud to be discharged or InJected upon completion of the last exploratory well. 2 Estimated well depth, 11,350 feet subsea. 3 Based on approximately 30 gal/day sewage and 30 gal/day gray water per person for average 60 to 70 persons. 4 Solid ~laste Disposal - 10 lb/trash/day/person plus drllllng rig operation combustible wastes. 8.4 So. lid Was~te Di~s~osal Ail combustible waste including trash from quarters, mud sacks, and garbage will be burned and reduced to ash in a diesel fired gun-fired burner incinerator. Incinerator residue and non- combustible waste will be backhauled to an approved onshore disposal site. Estimated quantities of solid waste are also shown on Table 3. 8.5 Air Emissions --. The prime movers on the drilling vessel will be standard items associated with contemporary drilling and marine equipment and are familiar to the Alaska Department of Environmental Conser- vat ion (DEC). Application has been made to DEC for approval of open burning of hydrocarbons produced from flow testing. 8.6 Commun ic~ti, ons Private telephone circuits will be available on the CIDS rig when drilling operations are being carried out. These circuits will access the Arctic Slope Telephone Association Cooperative system in Deadhorse through a microwave link. Both voice and data transmission will be able to occur simultaneously. VHF-FM communications will be maintained between the drilling vessel and the Deadhorse expediter. Marine radio communications will be maintained between the rig and all vessels enroute to and from the rig during open water periods. Aircraft VHF-FM communi- cations will be available for helicopter operations. A wind speed and direction indicator and a non-directional beacon will be maintained on the rig in support of VFR and IFR heli- copter flights. -68- 8.7 Food Service The drilling contractor will provide food service for the crew on the drilling vessel. He will be responsible for ensuring that all food is from an approved source, is properly refrigerated, and stored on shelves off the floor. Cleanliness will be maintained in the kitchen and dining facilities in compliance with applicable government regulations. The contractor will have a valid State of Alaska, Department of Environmental Conservation Food Service Permit. 9.0 SUPPORT SERVICES AND TRANSPORTATION Support of the drilling operation will utilize a variety of modes of transportation dependent on the season, ice conditions and weather. The GLOMAR BEAUFORT SEA I is capable of storing fuel sufficient for up to four months of continuous operation, as well as consumables and tangibles sufficient for three (3) wells. Consequently, major resupply will not be required until December 1987 or January 1988. An ice road may be constructed to the CIDS location early in 1988. Prior to that time any major resupply that may be required would be accomplished by Rolligon. If an ice road is not constructed to allow trucks access to the rig, Rolligon would remain the principal mode of resupply during the winter months. The approximate routing of the proposed ice road is shown in Figure 10. Frequent helicopter flights to the rig will be maintained throughout the operation period. An IFR equipped helicopter (Bell 412 class) will be contracted for support of the operation and stationed at Deadhorse Airport. Compatible IFR instrumen- tation will be installed on the rig. This aircraft will be dedicated to the Amerada Hess drilling operation and will be available 24 hours per day. The adverse weather and light S/~ps°n LO~Oon ~ Milne (~ Pl. Pt. 0 5 IO I'--! H H I Scale in Miles Figure 10 PROPOSED ICE ROAD SANDPIPER DRILLSITE o ISlon~s Bock Pt. ~ O NORTHSTAR "A" ISLAND NORTHSTAR 3 I(ClDS} O SEAL ISLAND DRILLSITE Reindeer Argo Is. ROUTE NORTHSTAR NO. 3 West Dock Gull~ Is. Prudhoe East Dock ~Niakuk Is. · Heold ~t. Deodhorse Airstrip Cross I~s. Is. IFR capability essential. The helicopter will be backed up by a second IFR aircraft which will be available during times when the primary helicopter is undergoing maintenance. Amerada Hess will establish a Deadhorse base to recieve and forward cargo, coordinate flights, and arrange other modes of transportation. This facility will be staffed by experienced expeditors and materialsmen. During periods of freeze-up and break-up and the weeks both preceding and following these events, transportation to and from the rig will be almost exclusively limited to helicopter. A possible exception would be the use of an ACV (air cushion vehicle), either self-propelled or towed by heavy lift heli- copter, if heavy loads exceeding helicopter sling load capability were required. During the open water season the rig will be supported by tug and barge operating from West Dock in Prudhoe Bay, as well as continuous helicopter operations. Major fuel deliveries will be made during the open-water season. Fuel transfer will be governed by an SPCC Plan (required by USCG) which will be kept aboard the vessel. Detailed logistical planning will be required to assure that adequate supplies of fuel, mud material, and other consumables are on the rig prior to the freeze-up/break-up periods. 10.0 DRILLING PROGNOSIS (Public Information) · The drilling program for the Northstar No. 3 exploratory well is covered in detail in the Application for Permit to Drill, filed with the Alaska Oil and Gas Conservation Commission. In the application the drilling mud program, casing design, formation evaluation program, cementing programs, hydraulics programs, and other engineering material is presented in detail. Much of the information is of a proprietary nature. The following sections cover the drilling programs within the limits of public informa- tion. 10.1 Ge019g ical The Northstar No. 3 well will be drilled from a surface location approximately 11,013 ft NSL and 4,284 ft EWL of lease block ADL 312799 (Figure 2). The well is programmed as a straight hole and the total depth will be approximately 11,350 ft TVD. The Ivishak formation is the principal exploration target, estimated to lie at approximately 10,900 ft TVD. The Kuparuk formation may also be evaluated as a secondary objective. The well will bottom in the base of the Ivishak formation. Relict permafrost is expected in the upper 1000 feet of the well. 10.2 Mud Logging and Collect,.ion of Sa. mP.les A qualified contractor will perform the mud logging service. A computerized mud logging unit will be employed which will supply drilling engineering data, formation gas and hydrocarbon moni- toring, and lithologic information on a continuous basis. The mud logging contractor will also collect, wash, and prepare cuttings samples as directed by the on-site geologist. A complete mud log and lithologic log will be prepared consisting of a detailed record and description of the sequence of strata penetrated, all shows of hydrocarbons, drilling penetration rate and other salient information. Drill cuttings will be collected every 30 ft from spud to the 13-3/8" casing point, and every 10 ft thereafter. Both washed and unwashed samples will be collected in sufficient quantities to supply all parties designated by the operator. In addition, cuttings samples will be collected for both geochemical and paleontological analysis as required by the operator. A mud sample will be collected at each easing point and at each significant change in the mud system. -72- A complete set of washed cuttings samples will be supplied to the State of Alaska in accordance with AOGCC regulations (20 AAC. 25.53'6.2). 10.3 Wireline Lo~ging and Velocity Surv. ey · The wireline logging program will be kept flexible to accommodate the specific formation evaluation objectives of the operator. The following logging program is representative of the wireline log data desired: ° Conductor Hole: No. Logs Surface Hole to approximately 3000 ft (through relict permafrost zone). Run 1: DIL/SP/SFL/LSS/GR combination tool 3000 ft to 9,700 ft TVD (top of Kingak Shale) Run 1: DIL/SP/BHC/GR Run 2: CNL/LDT/GR Run 3: Sidewall cores (if Kuparuk not conventionally cored ) 9,700 ft to 10,700 ft Run 1: DIL/SP/BHC/GR Run 2: CNL/LDT/GR 10,700 ft to 11,350 ft Run 1: DIL/SP/BHC/GR Run 2: CNL/LDT/NGS Run 3: RFT (optional) Run 4: Gyro survey Run 5: Velocity survey Ail logs will be run on 2" and 5" scales. Log data will be taped (LIS format or equivalent) and a field computed interpretation (cyberlock or equivalent) may be made on location. Further log evaluation will be made from the taped data by Amerada Hess Corporation. At the election of the operator, a velocity survey may be run prior to running the 7" liner described in Section 10.7. This survey will use a vibratory or air gun energy source. 10.4 Conventional and Sidewall Cori. ng Conventional cores may be cut in intervals of interest. The amount of actual coring attempted is heavily dependent upon drilling progress and lithology penetrated, and is at the discretion of the operator. Portions of any reservoir section recovered will be preserved for further analysis. The core will be slabbed vertically into two (2) parts. The slabbed core will be photographed and a core gamma log will be performed by a suitable contractor. Part "A" of the core will be reserved for description only. Part "B" will be available for analysis. Sidewall cores may be attempted in significant zones for reser- voir, lithological, paleontological, and geochemical analyses, at the option of the operator. Additional cores may be taken in massive reservoir beds or significant source bed sequences. An excess of sidewall cores will be planned in order to ensure full coverage. If conven- tional core recovery is good, the number of sidewall cores will be reduced over that interval. A preliminary lithologic description of both conventional and sidewall cores will be made at the wellsite and distributed as directed by the operator. -74- At the operator's discretion, cores designated as potential reservoir lithologies will be subject to (1) porosity, permea- bility, and grain density measurements and/or (2) thin section petrographic study. Those sidewall cores judged as non-potential reservoir lithologies will also be sampled for possible thin section petrography unless they are clay or coal. Argillaceous sidewall cores (shales, claystones, mudstones, marls, or other shaly or clayey lithologies), and coal sidewall cores may be subject to x-ray diffraction study. 10.5 Geochemical and Paleontological Program A basic geochemical well profile analysis may be carried out, at the option of the operator, particularly involving cuttings, sidewall cores, and conventional cores from the Kuparuk sands and Sad lerochit formations. The study, if performed, will be designed at a later date. The drilling fluid system will be kept as free as possible from contamination with organic and hydrocarbon materials to facili- tate any geochemical investigation. A paleontological study of drill cuttings and cores may also be made at the option of the operator. Age dating, determination of microfaunas and microfloras may be done with emphasis on foramin- ifera, palyomorphs and siliceaous nannofossils. Study of cuttings may be based on foraminifera determinations at appro- priate intervals, but should the foraminifera prove non- diagnostic, then either siliceous nannofossils or polynomorphs may be studied at increased intervals. 10.6 Drilling .M. ud. Pr?gr. am The drilling mud program will conform to the discharge regula- tions set forth in the EPA General NPDES permit (No. AKG284000) covering waters of the Beaufort Sea. While the specific mud program is being developed at the time of this application, it will include only those generic muds described in the NPDES permit and those additives which have EPA approval. In general, an undispersed bentonite spud mud will be used through the 133/8'' casing point (3000 ft TVD). Drilling the next hole section to approximately 9700 ft will use a low-solids non-dispersed mud system. This system will be weighted up to approximately 1'1.5 ppg through the Kingak shale section to approximately 10,700 ft. Additions of dispersants will be minimized. Below the Kingak shale a lightly dispersed low-solids mud system will be used, such as EPA approved Type 8 mud. Desired mud properties will be maintained under the direction of the on-site drilling foreman and a qualified mud engineer. Optimum solids control and fluid loss will be maintained, which is critical to successfully drilling the anticipated strati- graphic section. Contingency planning requires that a large inventory of barite and lost circulation material be maintained on the drilling vessel. These materials can be resupplied if required, but frequent adverse weather and sea ~conditions mandate that these products, as well as other backup mud materials be maintained on location. Sufficient materials will be available to completely rebuild the total circulating volume without resupply from shore. A non-freezing fluid (Arctic pack) may be placed in the 13-3/8" x 9-5/8" casing annulus prior to skidding the rig to the next location. 10.7 C~sing and Cementing Pro, grams. The casing and cementing programs for the Northstar No. 3 well are described in detail in the Application for Permit to Drill. The design is consistent with good oilfield practice and all -76- casing weights and grades are sufficient to resist anticipated downhole pressure differentials and mechanical loading. Hole and casing sizes are described below: D.epth .(TVD-KB) Hole Size Casing Size 400 ft + 26" 3000 ft + 17 1/2" 10,700 ft + 121/4'' 11,350 + 81/2" 20" conductor 133/8'' surface 95/8'' Intermediate 7" liner The wellhead sections used to land each of the successive strings of casing are also described in the Application for Permit to Drill filed with the AOGCC. 10.8 Testing Program, Disposal of Produced Test Fluids If the liner is run and a decision made to flow test the well, a testing program will be written at that time based on the known downhole conditions. Annular pressure activated test tools will be employed. Recovered liquids will be stored in portable tanks brought to the site for that purpose and gas will be flared from flare booms on the rig. All required permits will be obta~ined in advance of flaring. Equipment is presently installed on the GLOMAR BEAUFORT SEA I to also burn oil produced from flow tests. Amerada Hess may desire to utilize this equipment during the testing program. Applications for permits for this activity are being prepared. If a permit to burn produced oil cannot be obtained, the fluid will be reinjected (bullheaded) back into the formation from which it originated, or it may be disposed of by injection down the 133/8" x 95/8,, casing annulus. All permit restrictions and stipulations will be observed during any of these operations. -77- 10.9 Q.u.~alificati~_ons' 0f.,Ke.y P~ersonnel Ail wellsite operations will be under the direct supervision of the on-site drilling engineer. A wellsite geologist will also be on-site to supervise mud logging, sample collection, and core recovery. Both the engineer and the geologist will assure quality control in wireline logging operations. Additional operations personnel will be at the wellsite as specific special- ized activities dictate. Daily reports will be transmitted to the offices of Amerada Hess Corporation, and frequent telephone and datafax communications will monitor activities at the wellsite. Training and ~Drills Drilling. Personnel: - , Company and contractor personnel involved directly in drilling operations (including rotary helpers and derrickmen) will be trained in well control methods and in detection of abnormal pressures. Such training will be completed in approved company or industry schools before drilling is commenced. Blowout prevention drills will also be conducted as required by the Alaska Oil and Gas Conservation Commission. A list of personnel and their completed training will be main- tained on the drilling rig and will be available on request. Ail supervisory drilling personnel will be MMS certi- fied as operator's representatives both in surface and subsea applications. Ail personnel engaged on the project will receive Oil Spill Containment and Cleanup training as specified in the Oil Spill Contingency Plan. -78- Fire Drills: Procedures for emergencies such as f~res will be posted on the rig and in the quarters. Specific emergency responsibilities for crew members will also be posted at appropriate conspicuous places on the drilling rig. Fire, abandon rig and H2S drills will be conducted periodically for all crew members. Safety Meetings: Safety meetings will be conducted periodically to make crews aware of safety procedures and to review poten- tial sources of accidents, and the means of preventing them. Accident causes and corrective measures to be taken in the event of accidents will be discussed. An EMT/Radio Operator/Environmental Monitor person will be on the rig at all times, and will coordinate the safety program with supervisory personnel. Fuel Transfers: Fuel quantities in all storage and day tanks will be monitored daily. Fuel transfers from trucks or Rolligons (winter) and barges (summer) to the rig storage tanks will occur as required. A fuel transfer plan has been developed which addresses fuel flow diagrams, valving sequences, safety precautions and transfer procedures. One man will have the responsi- bility for all fuel transfers and he will be thoroughly trained in the above procedures. No fuel transfers will be made without this responsible party in atten- dance. U.S. Coast Guard approval of the fuel transfer plan will be obtained prior to startup of operations. 11 . 0 BLOWOUT PREVENTION PROGRAM AND EQUIPMENT · -' ,. ~ · -- ~ , ,, Ail drilling procedures employed on this project, whether automated or controlled by Company or Contractor personnel, are specifically designed and operated to prevent a loss of well control. The pr~imary method of well control utilizes hydrostatic pressure exerted by a column of drilling mud of sufficient density to prevent an undesired flow of formation fluid into the well bore. In the unlikely event primary control is lost, the following surface blowout prevention equipment would be used for secondary control: A 211/4'' 2000 psi working pressure (wp) annular diverter system will be nippled up on a 211/4'' weld-on flange on the conductor pipe prior to drilling the 171/2'' surface hole (Figure 11). Two 10" diverter lines will run to discharge points downwind from the drilling rig. The diverter lines will be equipped with a hydraulically actuated valves which will open the diverter lines concurrently with the closing of the annular preventer. In the unlikely event that high pressure, low volume surface gas is encountered, the wellbore fluids can be diverted downwind and gas vented to the atmosphere. After drilling the 171/2'' surface hole to approximately 3000 feet and cementing the 133/8'' casing back to the surface, the con- ductor will be cut off and a API 5000 psi wp SOW casing head will be installed. A 135/8'' 10,000 psi wp BOP stack will then be nippled up consisting of two sets of drill pipe rams and one set of blind rams plus a drilling spool and 5000 psi wp annular preventer (Figure 12). Choke and kill lines will be hooked such that the well can be closed in and killed in the unlikely event primary control is lost while drilling the next section of hole. This BOP stack will remain in place throughout all remaining drilling and testing procedures. A 10,000 psi wp choke manifold will be used in all well control operations after the 211/4'' diverter system has been removed. -80- 21 1/4" 2000 PSI WP ANNULAR DIVERTER 10' DIVERTER LINE8 10' DIVERTER LINES 10' 300 PSI WP HYDRAULICALLY-- OPERATED DIVERTER BALL VALVE8 --10' 300 PSI WP HYDRAULICALLY OPERATED DIVERTER BALL VALVES CONDUCTOR PIPE Figure 11 21 1/4" 2000 psi wp Diverter System. FILLUP LINE ~ ,I 5,000 PSI WP ANNULAR PREVENTER _ [ ! ~ FLOWLINE [ 1 3' KILL LINE l,lil[[ I i~,lll~ t'i ' 4' CHOKE LINE ~ ~ ~ ~ SPOOL ~ '~LLI~W~J.J.~~ WP CHOKE ---CHECK~ GATE--GATE-- lllfIIlll;ll(t ;lliItlll'l'" ~!i --GATE -- H.C.R.~ MANIFOLD VALVE VALVE VALVE _ V-AL'V-E ~[~ 15~1~1~ =1111,1 .~13 518' 10,000 ~x//~/////~_ 5000 ADAPTER~si x 13 5~8' ~~~~ WELLHEAD ~~~ =" = uu ~si FLANGE ' *~ SECTION ~* ~- Figure 12 13 5/8" BOP Stack 10,000 psi wp. -82- The blowout preventers will be actuated by a 375 gallon 3000 psi accumulator system with both air and nitrogen backups. Ail blowout prevention equipment and testing procedures will meet specifications required in the American Petroleum Institute Recommended Practice 953. Testing of all blowout prevention equipment will be conducted at least weekly and prior to drilling out the shoe of each casing string. Function tests and crew drills will be conducted daily. Primary well control will be maintained by over-balancing formation pressure with the drilling fluid. Automatic and manual monitoring equipment will be installed to detect any abnormal variations in the mud system and drilling parameters. A mud logging unit, manned by experienced personnel, will be in continuous use throughout the drilling operations and will monitor formation pressure, hydrocarbon shows, and loss or gain in mud pits. In the event that the well kicks, the blowout preventers will be used to shut in the well immediately and confine the pressure within a closed system. The casing program is designed so that any anticipated formation pressure can be safely shut in at the surface. The drilling representatives assigned to the drill site will have extensive training, including MMS approved well control training, together with actual experience in controlling and killing kicks. ~uch training is an ongoing program of Amerada Hess Corporation and Applied Drilling Technology, Inc. These personnel will be further supported by well-trained rig crews approved by the operator. Pressure resulting from a kick will be circulated out using industry approved methods, and the well will be restored to its normal operating condition. Leakoff tests or formation competency tests will be made after running each string of casing, both for well control information and as an indicator of the depth at which the next string of casing will be required. In the unlikely event that secondary control of the well is lost and premature well flow occurs, the operator has at its disposal specially designed contingency equipment, experienced back-up personnel, and an emergency spill containment unit which will be on location at all times. Section 14.0 describes Emergency Situation Procedures and Critical Operations in detail, and addresses the loss of well control. 12.0 OIL DISCHARGE CONTINGENCY PLAN (Stand Alone Volume) The prevention of pollution is given a high priority, exceeded only by the protection and safety of personnel. Proper equipment is provided on the rig, and at onshore facilities, so as to avoid the possibility of pollution. Personnel are trained in the use of this equipment and made aware of the potential consequences of spills. Good housekeeping practices will be emphasized and cleanup equipment will be provided at all stations to handle spills. The equipment and procedures for responding to oil spills at Northstar No. 3 location are detailed in the Oil Discharge Contingency Plan. The Oil Discharge Contingency Plan for the Northstar No. 3 well is a stand-alone volume and has been prepared and submitted to the Alaska Department of Environmental Conservation for review and approval. The Contingency Plan includes notification procedures, cleanup equipment inventories, spill trajectory analyses, response and cleanup techniques, and description of environmentally sensitive areas. 13.0 HYDROCARBON SULFIDE CONTINGENCY PLAN The area in which the Northstar No. 3 well is being drilled is not known to contain hydrogen sulfide gas in any formation above the Lisburne Formation. Since the subject well will bottom in the Ivishak Formation and not penetrate the Lisburne Formation hydrogen sulfide risk is considered extremely low. Nevertheless -84- a Hydrogen Sulfide Contingency Plan is being prepared as a separate Stand Alone document. Personnel safety is the prime concern of this plan. In the remote possibility that H2S gas is encountered, procedures will be in place to handle the situation. The Hydrogen Sulfide Contingency Plan will thoroughly familiarize all personnel with the following: Training for H2S emergencies including identification of safe briefing areas, Visible H2S Warning System. H2S Detection and Monitoring System. Personnel Protective Equipment. Ventilation Equipment. Metallurgical Equipment Considerations and Adjustments in the Mud Program. Flare Systems. Rig Evacuation Procedures. The basic premise for the protection of both personnel and the environment is containment. In the event of accidental release of H2S gas all safeguards and control procedures will be adhered to by all personnel. The rig will be positioned on location with the bow pointing at approximately 270° (due west). This will place the quarters upwind during prevailing weather conditions. 14.0 CRITICAL OPERATIONS. CURTAILMENT PLAN Any drilling or marine operation will be critical when the weather and/or sea ice conditions approach the design limits of the drilling rig or a drilling vessel. Potential critical operations are ballasting/deballasting, drilling, coring, running casing, logging or other wireline operations and drill stem testing. As a general rule no drilling or drilling related operations will commence or be conducted when wind gusts exceed 80 knots. These conditions are unusual for the subject area, with peak gusts in the 50 to 60 knot range being the extreme. As part of the contingency planning, the operator and/or con- tractor will implement an ice movement monitoring program which will supply real time data on ice loads against the drilling platform. In the unlikely eventuality that ice loads ever approach the design limits of the rig or the failure limits of the underlying soil, immediate action can be taken to secure the well until the condition(s) has improved. The drilling contractor has developed a manual of critical procedures (Global Marine Drilling Company - Critical Procedures, 1985) which detail operating and emergency procedures to be followed during ballasting/deballasting, towing, drilling and emergency operations. This manual is considered company propri- etary information, but can be made available for review by authorized regulatory personnel. No drilling operations will commence or be conducted when any of the following conditions exist: I · Operations will not begin until the Amerada Hess Corporation Drilling Representative is satisfied that the rig is properly rigged up to begin operations. The Drilling Representative will make an entry in the IADC Report stating his satisfaction to the above. · When there is an insufficient supply of drilling fluid materials on location to control the well. · When sufficient emergency containment and cleanup equipment is not on location or is not maintained in good working order. -86- · When the manpower required to safely conduct the drilling operation is not available. · · When any critical machinery needed to assure a normally safe operation is not operative. When the ice load on the drilling vessel approaches design limits. IMPORTANT: The above list is only a guideline. The decision as to what action to take during a given emergency, no matter what the cause, must be based on the judgement of the Amerada Hess Corporation Drilling Representative and the Drilling Contrac- tor's Supervisor. The persons in charge of the overall drilling operation is: C. R. Richard Manager, Engineering & Technical Services Amerada Hess Corporation 550 West 7th Street, Suite 1340 Anchorage, Alaska 99501 Tel: (907) 277-0873 Jon Marshall Operations Manager Glomar Beaufort Sea'I 510 "L" St., Suite 411 Anchorage, Alaska 9950 Tel: (907) 279-5449 If the drilling unit becomes partially or totally disabled while under contract to Amerada Hess Corporation, the priorities for action in all cases will be: 2. 3. 4. Personnel safety and evacuation, if required Prevention of pollution from well in progress Minimize property and rig damage Regulatory agency and Amerada Hess management notification. Ail contingency plans are developed with these priority objec- tives in mind. If the drilling rig is damaged to the point where it cannot be repaired on location, then, after evacuation of personnel (if necessary) and suspending the well in progress, the rig would most likely be repaired or replaced with the CIDS -87- remaining on location. A new rig could be brought in by barge, Rolligon or truck depending on the time of year and ice con- ditions, to continue drilling or plug and abandon the well in progress. Any debris that may have reached the seafloor would be removed in accordance with Coast Guard regulations and other agency requirements. Loss, 0r..Dama. ge to.. s.u~)po~rt_~cr, af_t The same priorities for emergency response in the event of a boat or helicopter accident will be followed as for a rig mishap. Since there are several barges, tugs, and helicopters routinely working in the coastal area of the Beaufort Sea (dependent on the season) there will be strong back-up capability to provide assistance in the event of one of these craft requires help. Assistance for search and rescue operations would be expected to come from other operators' boats and helicopters, other commercial vessels based in Prudhoe Bay, and the USCG along with other military organizations. If any support craft is lost from service to our operation, a suitable replacement for the support craft will be acquired before preceeding with any segment of the operation which depends on that support for its safety. 15.0 ENVIRONMENTAL TRAINING PROGRAM State/Federal Lease Stipulation No. 2 requires that any Plan of Operations include a proposed environmental training program for all personnel involved in exploration activities (including the personnel of contractors and subcontractors). This training program is subject to review and approval by the Director, Division of Oil and Gas. Amerada Hess Corporation has parti- cipated in the cost of the videotape presentation prepared by Mobil, Sohio, and Exxon. This training presentation has been -88- reviewed and found satisfactory by the Joint Federal/State Biological Task Force. The program will be given to all person- nel involved in the exploration activities. These tapes have been edited for industry-wide application under guidance from the Alaska Oil and Gas Association. The tapes are narrated by qualified instructors to insure that personnel understand and use techniques necessary to preserve archaeological, geological and biological resources. The program is designed to increase the sensitivity and understanding of personnel to community values, customs, and lifestyles in areas where such personnel will be operating. The required continuing technical environmental briefing program for supervisory and managerial personnel involved, including those of Amerada Hess Corporation, its agents, contractors, and sub-contractors has also been videotaped for industry-wide use. 16.0 RELIEF WELL DISCUSSION In the unlikely event that primary and secondary well control was lost, and a blowout occurred which could not be contained, the rig may have to be abandoned to prevent loss of life. This is an extremely remote possibility due to the extensive precautions taken to prevent such an occurr~ence. Fundamental to these precautions is the training required of all personnel involved in exploratory drilling operations and the safety equipment on the rig itself. All crew and supervisory personnel will be trained in accordance wit~ OCS Order No. 2 (GSS-OCS-T1). A list of personnel and training received will be available in the rig. If subsequent efforts to control the well failed, a relief well would be spudded from Seal or Northstar Island. The equipment and method used to transport a rig and supplies to either island would be dependent on the season and weather. Contractors capable of reacting to such an emergency are listed in the Alaska Clean Seas manual and are located in the Deadhorse-Prudhoe Bay Area. In cases of a blowout emergency, it is customary for all operators and contractors in the area to cooperate in making equipment and labor available. Sufficient drilling rigs, tubulars, wellhead equipment and materials (i.e., mud, cement, bits, fuel, etc.) are available on the North Slope to spud a relief well on an emergency basis. The rig and the aforementioned supplies would be transported to the relief island as soon as possible. Transportation during the ice season would be over ice roads or by Rolligon and by boat and/or barge during the open-water season. During freeze-up and breakup transportation would be by helicopter or possibly by an air-cushioned vehicle. The relief well drill site will be determined by consideration of meteorological forecasts, directional survey data from the blowout well and the indicated required depth of intersection-of the relief wellbore with the blowout wellbore. The relief well would always be located away from the blowout at a distance adequate for the protection of personnel and equipment. -90- 17.0 REFERENCES CITED Agerton, D., 1981. Large winter ice movements in the nearshore Alaskan Beaufort Sea. Proceedings of the Sixth Inter- national Conference on Port and Ocean Engineering under Arctic Conditions, Vol. 11, pp. 599-608. Agerton, D.J., 1983. Construction of an arctic offshore gravel island in 39 ft of water during winter and summr. Proceed- ings, 15th Annual Offshore Technology Conference, PP. 309-316. Agerton, D., and Kreider, J., 1979. Correlation of storms and major ice movements in the nearshore Alaskan Beaufort Sea. Proceedings of the Fifth International Conference on Port and Ocean Engineering under Arctic Conditions, Vol. 1, pp. 177-189. Amstrup, S.C., 1983. Marine mammals-polar bears. In: Sackinger, W.M., G. Weller, and S.T. Zimmerman~--eds. In press. OCSEAP: Beaufort Sea (Sale 87) synthesis report: Proceedings of a synthesis meeting - Chena Hot Springs, AK. Jan. 25-28, 1983. American Petroleum Institute, 1982. Planning, designing, and constructing fixed offshore structures in ice environments. 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Anchorage, Alaska. Bursa, A., 1963. Phytoplankton in coastal waters of the Arctic Ocean at Point Barrow, Alaska. Arctic 16:239-262. Carey, A.G. et al., 1978. Marine biota (plankton/benthos/fish). NOAA/OCSEAP, Interim Synthesis: Beaufort/Chukchi. Boulder, CO. 76 p. Carey, A.G., 1978. Marine biota, pp. 174-237. In: Environ. Assess. Alaskan Cont. Shelf, Interim Synthesis: Beaufort/ Chukchi. NOAA, Boulder, CO. Carey, A.G., R.E. Ruff, J.G. Castillo, and J.J. Dickinson, 1974. Benthic ecology of the Western Beaufort Sea continental margin; Preliminary Report. pp. 665-680. In: Reed and Sater (eds.), The Coast and Shelf of the Beaufort Sea, Arctic Institute of North America, Arlington, VA. Clark, C.W., 1983. The use of bowhead vocalizations to deter- mine the distribution of whales within the lead (1979 and 1980). Paper presented to the Second Conf. on the Biology of the Bowhead Whale, Balaena mysticetus, Anchorage, AK, March 7-9, 1983. Connors, P.B., C.G. Connors, and K.G. Smith, 1981. Shorebird littoral zone ecology of the Alaskan Beaufort Sea coast. NOAA/OCSEAP, Final Reports of the Principal Investigations, Vol. I, Biological Studies, R.U. 171. Boulder, CO. Craig, P.C. and L. Haldorson, 1981. Beaufort Sea barrier island-lagoon ecological process studies: Final Report, Simpson Lagoon. Part 4. NOAA/OCSEAP, Final Reports of the Principal Investigators. Boulder, CO. 295 p. Crane, J.J., and R.T. Cooney, 1973. The nearshore benthos, pp. 411-466. In: Alexander et al., 1975. Environmental studies of an Arctic estuarine ecosystem. University of Alaska, Institute of Marine Science, R-74-11. Croasdale, K., 1980. Ice forces on fixed rigid structures. In: Working Group on Ice Forces on Structures: A State-of-the- Art Report, Carstens, T., editor. U.S. Army Corps of Engineers, CRREL, pp. 34-106. Croasdale, K., Morgenstern, N., and Nuttal, J., 1977. Indenta- tion tests to investigate ice pressures on vertical piers. 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NOAA/OCSEAP, Annual Reports of the Principal Investigators, R.U. 196. Boulder, CO. Divoky, G.J., 1983. The pelagic and nearshore birds of the Alaskan Beaufort Sea. NOAA/OCSEAP, Final Reports of the Principal Investigators, R.U. 196. Boulder, CO. Dunton, K.H., E. Reimnitz, and S.V. Schonberg, 1982. An arctic kelp community in the Alaskan Beaufort Sea. Arctic 35(4):465-484. Eley, T. and L. Lowry, 1978. Marine mammals. Environmental Assessment of the Alaskan Continental Shelf, interim synthesis: Beaufort/Chukchi, Boulder, CO. NOAA/OCSEAP. Feder, H.M., and D. Schamel, 1976. Shallow water benthic fauna of Prudhoe Bay. pp. 329-359. In: Hood and Burrell (eds.), Assessment of the Arctic Marine Environment: selected topics, University of Alaska, Institute of Marine Science. Feder, H.M., Shaw, D.G., and Naidu, A.S., 1976. The nearshore environment in Prudhoe Bay, Alaska. In: The Arctic Coast- al Environment of Alaska, Vol. 1, University of Alaska, Institute of Marine Science, Fairbanks, R-76-1. Fraker, M.A., 1979. Spring migration of bowhead (Balaena mysticetus) and white whales (Delphinapterus leucas) in the Beaufort Sea. Can. Fish. Mar. Serv. Tech. Rep., 859:36. Fraker, M.A., and J.R. Bockstoce, 1980. Summer distribution of bowhead whales in the Eastern Beaufort Sea.~ Mar. Fish. Rev., 42:57-64. -93- Fraker, 'M.A. et al., 1981. Disturbance responses of bowheads and characteristics of waterborne noise. Behavior, disturbance responses and feeding of bowhead whales in the Beaufort Sea, 1980, ed. W.J. Richardson. Prepared for USDI, Bureau of Land Management, Washington, D.C. by LGL Limited, Ecological Research Associates, Inc., Bryan, TX. Frost, K.J. and L.F. Lowry, 1981. Feeding and trophic relation- ship of bowhead whales and other vertebrate consumers in the Beaufort Sea. Draft report submitted to the National Marine Fisheries Service, National Marine Mammal Labora- tory, Seattle, Washington. Gadd, P.E., Potter, R.E., Safaie, B., and Resio, D., 1984. Wave run-up and overtopping: A review and recommendations. Proceedings, 16th Annual Offshore Technology Conference, pp. 239-248. Galloway, B.J., W.B. Griffiths, W.J. Gazey, and J. Helmericks, 1982. An assessment of the Beaufort Sea stock of arctic cisco (Coregonus autumnalis) based upon the Derisco Model applied to catch and effort data from the Helmerick's commercial fishery. NOAA/OCSEAP, R.U. 467. BOulder, CO. Galloway, D.E., and Scher, R.L., 1982. The construction of man- made drilling islands and sheetpile enclosed drillsites in the Alaskan Beaufort Sea. Proceedings, 14th Annual Off- shore Technology Conference, pp. 437-448. Griffiths, W.B. and R.E. Dillinger, 1981. Beaufort Sea barrier island - lagoon ecological process studies: Final Report. Simpson Lagoon. Part 5: Invertebrates. NOAA/OCSEAP, Final Report, Vol. 8, R.U. 467. Boulder, CO. 198 p. Harding Lawson Associates, 1979. USGS geotechnical investiga- tion, Beaufort Sea, Alaska - 1979. Report prepared for the United States Geologic Survey. Harding Lawson Associates, 1983. Geotechnical observations and tests during construction of Seal A Gravel Island, Beaufort Sea, Alaska. Report prepared for Shell Oil Company. Harding Lawson Associates, 1984. Northstar site investigation, Tracts 46 and 47, Lease Sale BF-79, Beaufort Sea, Alaska. Preliminary report prepared for Amerada Hess Corporation. Hirsch, N.D., L.H. DiSalvo, and R. Peddicord, 1978. Effects of dredging and disposal on aquatic organisms. Technical Report No. DS-78-5. U.S. Army Corps of Engineers, Dredged Material Research Program. -94- Horner, R.A. and V. Alexander, 1972. Algal populations in Arctic sea ice, an investigation of heterotrophy. Limnology and Oceanography 17:454-458. Horner, R.A., K.O. Coyle, and D.R. Redburn, 1974. Ecology of the plankton of Prudhoe Bay, Alaska. University of Fairbanks, Inst. Marine Science, R-74-2, Sea Grant Report 73-15. 100 p. Horner, R.A., and G.C. Schrader, 1982. Relative contribution of ice algae, phytoplankton, and benthic microalgae to primary production in nearshore regions of the Beaufort Sea. Arctic 35:485-503. Johnson, S.R., 1979. Fall observations of westward migrating white whales (Delphinapterus leucas) along the central Alaskan Beaufort Sea Coast. Arctic, 32(3):275-276. Kovacs, A., and Mellor, M., 1974. Sea ice morphology and ice as a geologicl agent in the southern Beaufort Sea. The Coast and Shelf of the Beaufort Sea, pp. 113-161. Kranz, P.M., 1972. The anastrophic burial of bivalves and its paleoecological significance. Ph.D. Dissertation, University of Chicago. 117 p. Krogman, B., R. Sonntag, D. Rugh, J. Zeh, and R. Grotefendt, 1982. Ice-based census results from 1978-81 on the western arctic stock of the bowhead whale. Paper SC/34/PS6 presented to Int. Whal. Comm., Cambridge. 54 p. Lentfer, J., 1975. Polar bear denning on drifting sea ice. Jot. of Mammalogy 56(3):716-718. Lentfer, J.W., and RiW. Hensel, 1980. Alaskan polar bear denning, pp. 101-108. In: Martinka and McArthur (eds.), Bears--their biology and management. Fourth Int. Conf. Bear Re. and Manage., Kalispell, MT. 375 p. Leidersdorf, C.B., Potter, R.E., and Geoff, R.D., 1981. Slope protection for artificial exploration islands off Prudhoe Bay. Proceedings, 13th Annual Offshore Technology Confer- ence. Ljungblad, D.K., M.F. Platter-Rieger, and F.S. Shipp, Jr., 1980. Aerial surveys of bowhead whales, North Slope, Alaska. Final Rep. Fall 1979. Naval Ocean Systems Center Tech. Doc. No. 314. San Diego, CA. 181 p. Ljungblad, D.K., 1981. Aerial surveys of endangered whales in the Beaufort Sea, Chukchi Sea and Northern Bering Sea. Final Rep. Fall 1980. Naval Ocean Systems Center Tech. Doc. 449. San Diego, CA. 302 p. Ljungblad, D.K., S.E. Moore, and D.R. Van Schoik, 1983. Aerial surveys of endangered whales in the Beaufort, Eastern Chukchi and Northern Bering Seas, 1982. Technical Document 605. Naval Ocean Systems Center, San Diego, CA. 110 p. Lowry, L.F. and J.J. Burns, 1980. Foods utilized by bowhead whales near Barter Islands, Alaska, autumn 1979. Mar. Fish. Rev., 42(9-10):88-91. Madsen, O.S., and Grant, W.D., 1976. Sediment transport in the coastal environment. Report No. 209, Dept. of Civil Engrs., MIT, 105 p. Malme, C.I., and R. Mlawski, 1979. Measurements of underwater acoustic noise in the Prudhoe Bay area. Technical Memo- randum No. 513. Houston, TX: Bolt, Beranek, and Nauman, Inc. Marquette, W.M. and H.W. Braham, 1982. Gray whale distribution and catch by Alaskan Eskimos: A replacement for the bowhead whale? Arctic, 35:386-394. Masse, H., 1972. Quantitative investigations of sand-bottom macrofauna along the Mediterranean northwest coast. Marine Biology, 15(3):209-220. Matheke, G.E.M., and R. Hornet, 1974. Primary productivity of benthic microalgae in the Chukchi Sea near Barrow, Alaska. J. Fish. Res. Bd. Can. 31:1779-1786. Mayne, P.W., 1980. Cam-clay predictions of undrained strength. Journal of the Geotechnical Engineering Division, ASCE, Vol. 106., No. GT11, Proc. Paper 15816, Nov., pp. 1219-1242. McRoy, C.P., and J.J. Goering, 1974. The influence of sea ice on the primary productivity of the Bering Sea. Pages 403-421. In: D.W. Wood and E.J. Kelly (eds.), Oceano- graphy of the Bering Sea. Univ. of Alaska, Inst. of Marine Science, Occas. Publ. No. 2. Fairbanks, AK. Minerals Management Service (MMS), 1984. Diapir Field lease offering (June 1984). Vol. 1. Final Environmental Impact Statement, Alaska OCS Region. -96- NORTEC, 1981. Beaufort Sea drilling effluent disposal study. Prepared for the Reindeer Island Stratigraphic Test Well Participants, under the direction of Sohio Alaska Petroleum Company, Anchorage, AK. 329 p. Reese, A.M., 1978. Meteorological and oceanographic conditions, Arctic development project. Task 1/10, Part 1, Bellaire Research Center, Shell Development Company. Reese, A.M., 1981A. Ten-year ocean wave criteria in the Tern- Goose prospect. Technical Information Record BRC-422, Bellaire Research Center, Shell Development Company. Reese, A.M., 1981B. Oceanographic criteria for Seal prospect. Technical Information Record BRC-539, Bellaire Research Center, Shell Development Company. Reese, A.M., 1981C. Estimation of wave height reduction by shallow water at the Seal project. Technical Information Record BRC-539, Bellaire Research Center, Shell Development Company. Reimnitz, E., Toimil, L., and Barnes, P., 1977. Arctic Continental Shelf morphology related to sea-ice formation, Beaufort Sea, Alaska. Marine Geology, 28 pp. 179-210. Richardson, J. and S. Johnson, 1981. Waterbird migration near the Yukon and Alaskan coast of the Beaufort Sea. Arctic 34(2):108-121. Richardson, W.J. et al., 1983. Observations on the behavior of bowhead whales in the Canadian Beaufort Sea in the presence of marine industrial activities. Second Annual Conference Report on the Biology of Bowhead Whales (March 7-9, 1983), Anchorage, AK. Rugh, D.J. and M.A. Fraker, 1981. Gray whale (Eschrichtius robustus) signtings in Eastern Beaufort Sea. Arctic. 34:186-187. Schamel, D. 1978. Section on birds. NOAA/OCSEAP, Interim Synthesis: Beaufort/Chukchi. Boulder, CO. Schell, D.M., P.J. Ziemann, D.M. Parrish, K.H. Dunton, and E.J. Brown, 1982. Foodweb and nutrient dynamics in nearshore Alaskan Beaufort Sea waters. NOAA/OCSEAP, Final Report. 185 p. -97- Schwartz, J., and Weeks, W., 1977. Engineering properties of sea ice. Journal of Glaciology, Vol. 19, No. 81, pp. 459-531. Smith, T.G., 1980. Polar bear predation of ringed and bearded seals in the landfast sea ice habitat. Can. Jor. of Zoo. 58:2201-2209. Taylor, T., 1981. An experimental investigation of the crushing strength of ice. Proceedings of the Sixth International Conference on Port and Ocean Engineering under Arctic Conditions, Vol. 1, pp. 332-345. Tekmarine, Inc., 1982. Large-scale model studies of Arctic Island slope proteciton. Prepared for Shell Oil Company for Seal Island Design, 133 p. Tekmarine, Inc., 1983A. Slope protection monitoring program for 1982, Seal Island, Beaufort Sea, Alaska. Report to Shell Oil Company, 96 p. Tekmarine, Inc,, 1983B. Slope protection monitoring program for 1983, Seal Island, Beaufort Sea, Alaska. Prepared for Shell Oil Company, 65 p. Ward, E.G., and Reese, A.M., 1979. Summary of Beaufort Sea storm wave study, Arctic development project. Task 1/10, Part 2 and Task 2/15, Bellaire Research Center, Shell Development Company. Watanbe, A., Tashiho, Y., and Horikawa, K., 1979. Two- dimensional beach profile changes associated with on-off- shore sediment transport distribution. Proceedings, 26th Japanese Coastal Engineering Conference, JSCE, pp. 172-176. Weggel, R.J., 1976. Wave overtopping equation. 15th Coastal Engineering Conference, Vol., 3, Chapter 157, pp. 2737-2755. -98- EBA En neermg:': c. Geotechnical and Ma:;terials Engineers OTECHNtCA:L IN V E S T IG A T IO G E N ...... ' ........ ": "'i- ~?~i!: "~ :~. .~:<~ SITE~:.B,,~..~:R~!HSTAR- ~SEAL AREA B E AU.'FO R~T~.,i:S.E A, ALASKA 667 GEOTECHNICAL INVESTIGATION SITE B, NORTHSTAR - SEAL AREA BEAUFORT SEA, ALASKA FINAL REPORT 0501-4667 GEOTECHNICAL INVESTIGATION SITE B, NORTHSTAR - SEAL AREA BEAUFORT SEA, ALASKA FINAL REPORT prepared for: AMERADA HESS CORPORATION TULSA, OKLAHOMA prepared by: EBA ENGINEERING INC. EDMONTON, ALBERTA 0501 -4667 July, 1 987 EXECUTIVE SUMMARY EBA Engineering Inc. was retained by Amerada Hess Corporation to conduct a geotechnical investigation of four offshore sites in the Northstar - Seal Island area of the Beaufort Sea, Alaska. The aim of the investigation, conducted from the ice during the month of April, 1987, was to determine seabed soil conditions and engineering parameters appropriate for the future design of a gravel island or bottom-founded drilling structure. This report documents the findings of the investigation performed at one of the sites, designated site B. Site B is located in approximately 43 feet of water. The field investigation consisted of drilling and sampling one central borehole and three perimeter boreholes at a radius of 400 feet. The boreholes ranged from 30 to 75 feet in depth, and recovered samples were subjected to classification, shear strength and consolidation tests. Cone penetrometer tests were also performed at central and perimeter locations to depths of up to 15 feet. Surficial soil conditions at Site B comprise two distinct units: a thin mantle of soft or loose Holocene silts and silty sands, overlying dense Pleistocene sands and gravels. The uppermost unit ranges in thickness from 4.5 to 8 feet, and is thinner in the eastern portion of the site. The gravel was found to be frozen at a depth of 54 feet below seabed. The cohesive silt has an apparent preconsolidation pressure of 1.5 ksf and an undrained shear strength in the range of 400 to 600 psf. The normally-consolidated Su/p ratio is approximately 0.31. Effective friction angles for the surficlal silts and silty sands are estimated to be between 33 and 35 degrees. Minimum friction angles for the dense sands and gravels are inferred from the results of cone penetration tests to be 40 and 44 degrees, respectively. The report presents recommendations for the geotechnical evaluation and design of a gravel island or bottom-founded structure at the site. The site is considered generally suitable for deployment of a structure or island; however, detailed structure-specific analysis of stability, sliding resistance, and deformations should be performed in connection with any proposed installation. i) ii) iii) v) 1.0 2.0 3.0 4.0 5.0 TABLE OF CONTENTS Title Page Executive Summary Table of Contents List of Figures and Tables INTRODUCTION 1.1 1.2 1.3 Project Description Project Scope and Objectives Report Format FIELD PROGRAM 2.1 General 2.2 Drilling and Sampling 2.3 In Sltu Testing LABORATORY TESTING 3.1 Classification and Index Testing 3.2 Strength and Consolidation Testing SOIL CONDITIONS 4.1 4.2 4.3 Geological Setting General Soil Conditions Soil Properties 4.3.1 Classification and Index Properties 4.3.2 Consolidation and Stress History 4.3.3 Shear Strength DISCUSSION AND RECOMMENDATIONS 5.1 5.2 5.3 5.4 General Implications for Bottom-Founded Structures and Gravel Islands 5.1.1 Bottom-Founded Structures 5.1.2 Gravel Islands Installation and Setdown Conditions 5.2.1 Skirt Penetration Resistance 5.2.2 Contact Pressures Sliding Resistance 5.3.1 Silts 5.3.2 Sand and Gravel Settlements PAGE 10 10 10 11 12 12 13 13 13 14 15 iii TABLE OF CONTENTS (continued) 6.0 CLOSURE PAGE 15 Appendix A Appendix B Appendix C Appendix D Appendix E Appendix F Summary of Field Operations Borehole Logs Cone Penetration Test Results Summary of Laboratory Test Results and Grain Size Distributions Shear Strength Test Results Consolidation Test Results iv LIST OF FIGURES Figure Description General Location Plan Borehole and CPT Locations, Site B Schematic Arrangement of Cone Penetration Moisture Content Profiles, Site B Skirt Penetration Resistance Testing Equipment LIST OF TABLES Table Summary Description of Shear Strength Test Results 0501 -4667B ~---"~-.,. Pa ge 1 July, 1987 i . 0 INTRODUCTION 1.1 Pro~ect Description EBA Engineering Inc. (EBA) has been retained by Amerada Hess Corporation to conduct a geotechnical investigation of four offshore sites in the Northstar - Seal Island area of the Beaufort Sea, Alaska. The investigation was carried out from the ice during the month of April, 1987, and involved four sampled borings at each site. In situ cone penetrometer testing (CPT) was carried out, together with a comprehensive laboratory testing program on recovered samples. The investigation was authorized by Mr. P.A. Dysert of Amerada Hess by a letter of contract dated April 21, 1987, and the work was performed in consultation with Mr. C.R. Richard. The four sites are designated A, B, C and D, and their locations were specified by Amerada Hess. Water depths at the sites range from 38 to 43 feet. This report documents the soil conditions, engineering properties and design implications for Site B. Findings from the other three sites are presented in a separate report. 1.2 Pro~ect Scope and Objectives The purposes of this study were to investigate seabottom soil conditions at each of the four sites and to develop geotechnical parameters appropriate for the design, and permitting of a gravel island or bottom-founded structure. The approach to obtaining seabed soil data was similar for each site, and consisted of drilling and sampling one central borehole and three perimeter boreholes at a radius of approximately 400 feet. Boreholes were advanced to depths of between 30 and 75 feet, and disturbed and undisturbed samples were ~ Pa ge ~ 0501 -4667B ,~--~ ~ July, 1 987 recovered for laboratory testing. Cone penetrometer tests were also performed at central and perimeter locations to depths of up to 15 feet. Laboratory testing comprised classification and index testing, and assessment of shear strength and consolidation properties. The results were interpreted to provide des£gn recommendations in respect to installation, bearing capacity, settlement and lateral sliding resistance of a structure or island. 1.3 Report Format This document represents a complete report for Site B. It contains a summary of soil conditions, results of laboratory and field testing, and an interpretation of the engineering properties of the soils. Complete details of the field program, testing procedures and results are presented in the Appendices. 2.0 FIELD PROGRAM 2.1 General The field program at Site B was carried out from the ice between April 26 and April 29, 1987, and comprised four sampled boreholes and four cone penetrometer (CPT) probes located at the central and perimeter points of a circle approximately 400 feet in radius. The general location of the study area is shown in Figure 1, and the detailed boring and CPT. locations for Site B are shown in Figure 2. The water depth at the site is approximately 42 feet. 2.2 Drillin$ and Sampling Drilling was carried out using a track-mounted Simco 4000 top drive hydraulic rotary drill rig provided by Tester Drilling Services of 0501 -4667B Page 3 July, 1 987 Anchorage, Alaska. The drilling system also included a track-mounted logging shack and tool carrier. Drilling operations were performed on a single shift, 14 hours per day basis during the first five days of the project, then a double shift, 24 hours per day operation was employed. Each crew consisted of an engineer/geologist, driller and driller's helper. The drilling area was enclosed in a canvas wind break and heated to provide a suitable working climate for men, equipment and the use of drilling fluids. Further details of the operation are presented in Appendix A. The drilling was performed using open-hole rotary drilling techniques, with 4 inch O.D. drill pipe and an open center drag bit. The borings were generally advanced using seawater as the circulating fluid; however, drilling mud (saltwater gel) was used to form a viscous mud when gravel was encountered and prohibited drilling below 30 feet. The drilling mud was used in order to advance the soil boring to specified depths below 30 feet. Cuttings and drilling fluids were discharged on the sea-floor. Boring B-1 was advanced to a depth of 55 feet below seabed, while the remaining borings extended between 31.5 and 35.5 feet. Samples were taken using wireline recovery techniques and 3.0 inch push or drive samplers. Samples were taken at intervals of 3 to 5 feet in the surficial sediments and at 5 to 10 foot intervals in the underlying gravel. Where possible, undisturbed samples of the surficial materials were obtained using thin-walled tubes; this was generally possible in the cohesive silts. Otherwise, a 3.0 inch O.D. split spoon sampler was driven with a 175 lb. downhole hammer to collect disturbed samples. Samples were logged in the field by the engineer/geologist, and subjected to strength index tests (torvane and pocket penetrometer) where appropriate, and temperature measurement. Samples were subsequently sealed against moisture loss and shipped under controlled temperature conditions to EBA's Anchorage and Edmonton laboratories. 0501-4667B ~-~ Page 4 July, 1 987 Detailed logs of the four soil borings are presented In Appendix B. 2.3 In Sltu Testin~ Cone penetrometer testing was carried out at four locations, to depths of up to 10 feet below seabed. In each case, the test was terminated upon refusal, usually in the gravel stratum. The CPT testing was performed using the Hogentogler cone system provided and operated by ConeTec Investigations Ltd. of Vancouver, B.C. The multi-channel electric cone was pushed continuously into the soil at a constant rate using a hydraulic ram mounted on the Slmco 4000 drill rig. Tip resistance, sleeve friction, dynamic pore pressures, inclination and temperature were recorded automatically by an IBM-compatible based data acquisition system. The cone system was operated from the ice surface. The interval through the water was supported by an 8 inch double wall casing and an inner support string of BX rod. The casing was set to the seafloor and clamped at the drill table. The drill was anchored to the ice with an ice anchor connected from the drill table to the bottom of the ice sheet. The arrangement for CPT testing is shown schematically in Figure 3. Results of the CPT are Corrected for unequal areas and other effects, and are presented in the form of depth profiles for tip resistance, sleeve friction, friction ratio, dynamic pore pressure and pore pressure ratio. The results from the four locations at Site B are presented in Appendix C. 3.0 LABORATORY TESTING 3.1 Classification and Index Testin~ All recovered samples were subjected to basic laboratory testing to determine soil classification and index properties. This comprised moisture 0501 -4667B ..... Page 5 July, 1 987 content determination, grain size analysis using sieve and hydrometer methods, Atterberg limit tests and, where appropriate, organic content tests. Test results are presented on the borehole logs, Appendix B, and in summary tables in Appendix D. Grain size distribution curves are also contained in Appendix D. 3.2 Strength and Consolidation Testin~ Selected undisturbed samples of cohesive silt were subjected to shear strength and consolidation testing. The number of tests of each type were limited due to the relatively thin silt strata and hence the small number of undisturbed samples. Strength and consolidation testing comprised the following: (a) Consolidated undrained triaxial tests One isotropically consolidated, undrained triaxlal test was carried out at an effective consolidation stress of 500 psf. Pore pressure measurements were made throughout the shearing portion of the test. (b) Direct simple shear tests Two constant volume drained direct simple shear tests were performed us£ng a Wyckham Farrance apparatus designed to conduct tests similar to those pioneered by the Norwegian Geotechnical Institute (NGI). A constant volume drained test is equivalent to a consolidated undrained test with pore pressure measurement. The tests were carried out at vertical consolidation stresses of 2.0 and 4.0 ksf. (c) Consolidation tests A standard one-dimensional oedometer test was performed on one sample of silt. The loading procedure involved incremental loading, with each step sustained to the end of primary consolidation. An unload-reload cycle was incorporated. O501 -4667B Page 6 July, 1 987 Detailed results of the shear strength tests are presented in Appendix E, and consolidation test results are included in Appendix F. The results are discussed in a subsequent section. 4.0 SOIL CONDITIONS 4.1 Geolo$ical Settin$ Stratigraphic conditions on the inner Beaufort Sea shelf in the Prudhoe Bay area have been influenced by a complex series of sea level fluctuations that occurred during the Pleistocene. Eustatic sea level changes caused by worldwide glacial epochs have exposed the inner shelf to alternating conditions of continental and marine deposition, and subaerial exposure with accompanying arctic temPerature regimes. During the Pleistocene, the sea level is believed to have reached as high as 330 feet above present levels, and more than 425 feet below. Most of the Quaternary deposits in the area comprise alluvial and fluvial materials deposited during sea level regressions. These materials are largely sands and gravels, comprising reworked Tertiary materials and transported materials from the Brooks range. The sand and gravel form a thick layer that overlies the Tertiary Sagavanirktok formation over most of the area. Permafrost formed in these deposits during subaerial exposure, and still exists despite gradual degradation as a result of subsequent inundation. Surficial Holocene materials comprise fine-grained marine sediments deposited during the most recent transgressions, together with reworked Pleistocene soils and present day deltaic and littoral deposits. These soils are typically clayey and sandy silts and fine sands, and frequently contain organics indicative of a possible lagoonal environment. Ice scouring activity occurs in the area, but gouge features are less frequent and of shallower relief than in some areas to the west and in 0501 -4667B --- Page 7 July, 1987 ~ deeper water. Local seabed relief is reported to be less than 2 feet, and more commonly 1 foot, in the vicinity of the sites of interest. 4.2 General Soil Conditions Surflcial soil conditions at Site B comprise two distinct units: a thin mantle of soft or loose Holocene silts and silty sands, overlying dense Pleistocene sands and gravels. Detal~ed stratigraphic information is presented in the borehole logs in Appendix B. The stratigraphy is summarized in the following table: SOIL DESCRIPTION DEPTH RANGE TO RANGE OF TOP OF LAYER THICKNESS (feet) (feet) SILTY SAND, fine, loose; and SANDY SILT, soft to medium; trace of organics, trace of gravel SAND, medium dense SANDY GRAVEL, clean, dense to very dense, up to 2.5" sizes; frozen below 54 feet 0 4.5 - 8.O 5.0* 0 - 2.5 4.5 - 8.0 >25 NOTE: * where present A thin veneer of loose silty sand exists at the seabed surface across the entire site. The soft sandy silt was encountered at all boring locations, but in general is thinner in the eastern portion of the site (Boring B-4 and CPT B-4). The surface of the sandy gravel is closest to the seabed surface in the eastern portion, occurring at a depth of approximately 4.5 feet. Gravelly sand layers exist at depth within the Pleistocene strata, below the uppermost occurrence of gravel. The frozen gravel at 54 feet is reported to be well-bonded, with no excess ice. -- - ..... Pa ge 8 0501 -4667B July, 1 987 4.3 Soil Properties 4.3.1 Classification and Index Properties Results of the classification and index testing are presented in Appendix D. The variation of moisture content with depth is shown for all the borings in Figure 4. The following paragraphs summarize the general characteristics of the soils present. (a) Surficial sands and silts Moisture contents in the uppermost sands and silts range between 13 and 51 percent. The lower values correspond to sands, and the higher values represent organic materials. In general the moisture contents for the silts are between 20 and 30 percent. Two organic content tests indicated approximately 13 percent organics in certain samples. Grain size analyses on these materials indicate that silt content varies between 15 and 45 percent, with the finer soils displaying low to medium plasticity. Although most soils contain only fine sands, up to 30 percent gravel sizes were observed in some samples. (b) Lower sands and gravels Moisture contents in the Pleistocene soils vary between 3 and 16 percent, with the gravels generally displaying values below 10 percent. Gradation curves for these materials indicate primarily uniform fine gravels, with 10 to 30 percent sand sizes and some coarse gravel. However some samples are well-graded gravelly sands, or gap-graded fine sands with high gravel contents. Gravel sizes up to 2.5 inches have been observed in recovered samples. 0501-4667B .~-~'~, Page 9 July, 1 987 4.3.2 Consolidation and Stress History The surf£cial soils are generally regarded as being in a loose, or normally consolidated, state. However, in common with many areas of the Alaskan Beaufort shelf, the near surface silts display an apparent degree of overconsolidation that is not readily explained by mechanical loading and unloading. One consolidation test performed on a sample of silt from this site indicated a preconsolidation pressure of 1.5 ksf, corresponding to an overconsolidation ratio (OCR) of approximately 7. The observed compression index Cc and recompression index Cr are 0.20 and 0.02, respectively. The coefficient of consolidation cv averages 0.006 cm2/s, and the average permeability k is 2 x 10-5 cm/s. 4.3.3 Shear Strength (a) Surficial sands and silts Based on the loose state of the surficial silty sands, as observed during drilling and sampling, and confirmed by CPT measurements, the angle of friction is inferred to be in the range of 33 to 35 degrees. Strength index tests . performed in the field (torvane and pocket penetrometer) on samples of silt indicate undrained shear strengths of 400 to 600 psf. Two direct simple shear tests and one consolidated undrained triaxial test were performed on samples of the silt. The direct simple shear tests gave normalized shear strengths (Su/p) of 0.34 and 0.31 at consolidat£on stresses of 2.0 and 4.0 ksf respectively. The triaxial test gave a failure deviator stress (at peak stress ratio) of 860 psf at a consolidation stress of 500 psf. This test was carried out at an OCR value of approximately 3, and the material displayed dilatant behaviour. The results of the shear strength tests are summarized in Table 1. 0501-4667B .... ~-~ Page July, 1987 CPT tip resistances in the silt intervals were mostly in the range of 5 to 30 tsf, although some values in excess of 50 tsf were observed. These high values may have been influenced by adjacent or included sand or gravel. There ls limited laboratory strength test data with which to calibrate the CPT measurements. However, use of a cone factor of 20 yields a minimum in sltu undrained shear strength of 500 psf. Interpretation of the CPT is discussed further in a subsequent section. (b) Lower sands and gravels The underlying Pleistocene sands and gravels are dense to very dense. CPT tip resistances of between 50 and 150 tsf were measured in the sands, and values of 200 to 300 tsf were recorded in the gravels prior to cone refusal. Existing correlations between cone resistance, relative density and friction angles suggest minimum values of friction angle of 40 degrees in the sands and 44 degrees in the gravel. Validation of these strengths is difficult without quantitative relative density measurements; however, the values are consistent with experience elsewhere and are believed appropriate. 5.0 DISCUSSION AND RECOMMENDATIONS 5.1 General Implications for Bottom-Founded Structures and Gravel Islands 5.1.1 Bottom-Founded Structures A major issue governing the design of bottom-founded structures for the Beaufort Sea is the provision of adequate lateral resistance against ice loading. The lateral resistance is a function of the shear strength of the seabed soil at the governing potential failure surface. Depending on whether the soil behaves in a frictional or cohesive (undrained) manner, the sliding resistance may also depend on the on-bottom weight, base area, and the efficiency of the contact between base and soil. 0501-4667B -~ Page July, 1 987 ~-'~", The efficiency of contact depends to some extent on the nature of the seabed surface and, for a structure with base shear skirts, on the mode of act£on of the skirts. The latter is also influenced by the resistance to penetration of the skirts. Skirt penetration, base contact conditions and shear strengths appropriate for sliding resistance determination are addressed in subsequent sections. For bottom-founded structures designed for the Beaufort Sea, bearing capacity is seldom a problem, due to the small thickness of potentially weak material in relation to the width of the structure. The near-surface Pleistocene soils present in the Seal-Northstar area will provide adequate assurance against bearing failure. Settlements may occur, however, particularly if the applied load exceeds the preconsolidation pressure of the surficial sediments. A discussion of settlements is given below. 5.1.2 Gravel Islands The design of gravel islands for intermediate water depths in the inner Beaufort shelf is generally driven by surface working area criteria and by the requirement for stable, adequately protected slopes. Sliding resistance, for an island that meets the above conditions, is often not an issue; however, the available shear resistance mobilized along a potential weak layer at seabed should be compared with imposed ice loadings. The major geotechnical issues with respect to gravel island design, aside from construction material requirements, are settlements and slope stability. The latter aspect depends on slope geometry and seabed shear strength. Shear strength and settlements are discussed with respect to island design, in the following sections. 0501-4667B Page 12 July, 1987 -~ 5.2 Installation and Setdown Conditions 5.2.1 Skirt Penetration Resistance Skirt penetration resistance may be determined semi-empirically using CPT data, since the process of skirt insertion is similar to that of cone penetration. The applicable equation has been found to be reliable for several North Sea structures and is given as follows (DnV, 1977): q ~ Kt.qc(D).At + 2.Kf.qc(D,)As where: q --resistance per lineal foot of skirt Kt = empirical coefficient (0.6) qc(D) ~ CPT tip resistance at depth D At -- area of skirt tip per lineal foot Kf ~ empirical coefficient (0.003 sands, 0.04 clays) qc(D') = average CPT tip resistance over depth D As = side area of skirt Equation 1 has been applied to the CPT results obtained for Site B to determine the unit penetration resistance for skirts deployed at the site. For illustrative purposes, the skirts are assumed to be 7/8 inch thick steel plate. The results are summarized in Figure 5. The minimum penetration resistance encountered to a depth of 5 feet is 2.1 kips/foot; the maximum is 18.0 kips/foot (at 4 foot penetration). A reasonable intermediate value is 8.3 kips/foot at 5 feet depth. A value of 22.7 was computed for one profile at a depth of 6.1 feet, where CPT refusal was experienced. It should be noted that skirt stiffeners should be taken into account when applying the unit skirt resistance over the entire base of a structure. 0501-4667B ---~ Page ~3 July, 1 987 5.2.2 Contact Pressures The average bearing pressure is determined by the total weight of a structure divided by the actual area of base contact. The latter may be less than the total base area due to seabed irregularities. Where the skirts carry an appreciable vertical load due to penetration resistance, the weight remaining for distribution over the base is reduced accordingly. Redistribution of vertical load from skirts to base may occur with time. Seabed irregularities can give rise to stress concentrations, whose magnitude £s dictated by the shear strength of the soil and the geometry of contact. For Site B, where the seabed relief is typically 2 feet or less, the maximum local stress arising from contact with sand is not likely to exceed 15 ~sf. Where contact is with soft silt, the maximum value would be in the order of 3 ksf. Surface boulders, if present, could give high local concentrations; however, stresses would probably be limited as such features would punch through into underlying softer soil. The degree of base contact and the distribution of contact stress affects the mode of action of shear skirts, and hence their efficiency. If mobilization of shear resistance over the entire base area is desired for lateral resistance, particularly in soft silts, the efficiency of the skirt system should be examined in detail. 5.3 Sliding Resistance 5.3.1 Silts The most critical layer with respect to sliding ~resistance at Site B is the soft sandy silt. This material displays an in sltu undrained shear strength in the range of 400 to 600 psf. Under loading by a structure or gravel island, this value will increase somewhat due to consolidation, a process that would be reasonably rapid due to the relatively permeable nature of the soil. O501-4667B Page 14 July, 1 987 The shear strength Su, due to application of a vertical effective stress p, may be estimated for Site B by the SHANSEP equation: 0.8 Su/p ~ 0.31.(0CR) ..... (Eq. 2) where OCR is the overconsolldation ratio pc/p, Pc being the preconsolidation pressure. If p exceeds Pc' which at Site B has been measured at 1.5 ksf, the ratio Su/p is equal to 0.31. For a gravity structure, the average stress imposed on the seafloor may be 1.5 to 2.5 ksf, which would give rise to an undrained shear strength, applicable to sliding resistance, of 460 to 770 psf. For a gravel island, under which the stress increase could be, say, 5 ksf, the resulting undrained shear strength would be 1.5 ksf. This value would be applicable beneath the centre for sliding resistance, while a lesser value beneath the side slopes, due to the decreasing fill height, could be determined for slope stability assessment. 5.3.2 Sand and Gravel If a structure is equipped with shear skirts capable of efficiently transferring the lateral load directly into the underlying dense sand or gravel, the frictional resistance of these materials may be relied upon. The efficiency of the skirts with respect to this function should be evaluated, particularly where there are overlying weak soils and where there may be incomplete base contact. Recommended friction angles for sliding resistance in these materials are 40 and 44 degrees for dense sand and dense gravel respectively. The entire structure weight, including that required to cause skirt penetration, may be used to determine sliding resistance. 0501-4667B ,'-~-~ ~ --~. Page July, 1 987 5.4 Settlements Consolidation settlements in the silts may be determined on the basis of a compression index of 0.20 or a recompression index of 0.02. The former is applied to stress increments above the preconsolldation pressure, while the latter is applied at levels below the preconsolldation pressure. Settlements In the order of 0.5 foot may be anticipated under gravity structure loadings, depending on actual bearing pressures, while settlements under gravel island loadings may be 0.7 to 1.0 foot. Settlements of the underlying granular materials will be minimal. For a gravity structure whose weight is largely transferred to the underlying sands and gravels through skirt penetration resistance, settlements will be small. 6.0 CLOSURE This report summarizes the findings of a geotechnlcal site investigation performed at Site B in the Northstar - Seal area of the Beaufort Sea. Recommendations are provided for the evaluation of a bottom-founded structure or gravel island at the site. The site is generally considered suitable for deployment of a structure or island; however, detailed structure-specific analysis and/or design is beyond the scope of this report. We would be pleased to provide such services upon request. Page 0501-4667B July, 1987 Respectfully submi tted, EBA Engineering Inc. D.R. Williams, Ph.D. Senior Project Engineer D.W. Hayley Senior Vice Pres£dent DRW:chb 0501-4667B .~ ~--~ Page 17 July, 1 987 ~ LIST OF REFERENCES DET NORSKE VERITAS, 1977. Rules for the Design, Construction and Inspection of Offshore Structures, Appendix F, Foundations. ! [ ! ! ! ! ! ! ] I ] ! ] ! ] ] NCE~H STAR I~ NORTH ST~""'~,,,. AMERADA F-ESS BF - 46 AIVERADA FES~ 39-01 R 13 "E-- ~TE D AMOCO OC~-O 179 StlE c -I- TX. EAST BF-~ FIGURE 1 GENERAL LOCATION PLAN 6,038,8OO 6,038,600 6,038,400 6,058,200 6,038,000 6,0,57,800 650,200 650,400 650,600 650,800 651,000 651,200 DESCRIPTION N E LATITUDE LONGITUDE C/L//BH- 1//CP T- 1 6,0,38,270 650,6,35 70'50'41.8" 148'46'02,1" BH-2 6,0`58,670 650,626 70'50'45.8" 148'46'02.1" CPT-2 6,038,476 650,976 70'50'4`5.8" 148'45'51.9" BH-,5 6,0.38,076 650,98,3 70'.30'`59.9" 148'45'51.9" CPT-3 6,038,870 650,640 70'`50'`57.9" 148'46'02.2" EIH-4 6,038,064 650,290 70'50',39.9" 148'46'I 2.3" CPT-4 6,038,464 650,28,5 70',50'43.8" 148'46'1 I i i FIGURE 2 BOREHOLE AND CPT LOCATIONS, SITE B 4667-00! ICE 'B' ROD SIIviCO 4000 DRILL RIG LOGGING SHACK WITH RECORDING EQUIPMENT MOUNTED ON FN-60 NODWELL CARRIER SLED WITH CABLE PRETHREADED THROUGH CONE RODS 8 INCH DOUBLE WALL CASING CONE ROD SEABED FRICTION SLEEVE CONE TIP 4667-005 FIGURE 3 SCHEMATIC ARRANGEMENT OF CONE PENETRATION TESTING EQUIPMENT 0.0 0 10 20 3O 4O 50- 60 70 80- 0 I FIGURE 25.0 , ! MOISTURE CONTENT (%) 50.0 · 0 II ' ' · 75.0 I LEGEND cB-1 o 8-2 · B-5 o B-4 MOISTURE CONTENT PROFILES, SITE B 100,0 I 4667-006 0 OI PENETRATION RESISTANCE (kips/foot) 6 $ 10 12 14 16 2O LEGEND a CPT1 ~ CPT2 o CPT3 ~, CPT4 22 24 4~67-007 FIGURE .5 SKIRT PENETRATION RESISTANCE (7/8 INCH STEEL SKIRTS) i ! ] ] ] ] ! I ] ] ! ] 1 1 i ! I ! ] TABLE 1 SUMMARY OF SHEAR STRENGTH TEST RESULTS TEST TEST CONSOLIDATION PEAK DEVIATOR FAILURE(~) PEAK SHEAR TYPE(2) STRESS STRESS DEVIATOR STRESS STRESS (ksf) (ksf) (ksf) (ksf) FAILURE STRAIN (%) CIU-1 CIU 0.5 0.89 0.86 SS-1 DSS 2.0 w w 0.68 6.8 20.2 SS-2 DSS 4.0 w ~ 1.26 25.4 NOTES: 1. All tests were performed on Sample 2, Borehole B-2, depth 3.0 to 4.5 feet. 2. CIU = Consolidated (lsotropic) undrained trlaxial test. DSS = Direct simple shear test. 3. Failure in trlaxlal test defined as peak stress ratio (peak obliquity). NORMALIZED STRENGTH (Su/p) 0.86 0.34 0.31 APPENDIX A SUMMARY OF FIELD OPERATIONS Time and Event Summary Amerada Hess Corporation Time Event April 19, 1987 1430 hr. 1650 hr. 1830 hr. 2000 hr. 2030 hr. April 20, 1987 0630 h r. 0700 hr. 0820 hr. 0840 hr 0930 hr. 1130 hr. 1230 hr. M. Schlegel at Anchorage airport. Flight delayed - mechanical problems. Left Anchorage for Deadhorse. M. Schlegel at Deadhorse - Prudhoe Bay Hotel. Met with GSL. Rolligon ready for survey. Met with Dave Fillucci, surveyor. Made arrangements to .start survey in morning. Called Kurt Stangl, EBA, at home. Kurt said cardinal locations at drill sites 150 feet off center location. Loaded rolligon with survey equipment (re- conduit, stakes etc.). Left for West Dock. At West Do c~, wait for Dave Fillucci to arrive. Weather -20 F, ice fog, visibility <1/2 mile. Radio call from GSL. Kurt Stangl had called and said cardinal locations were to be 400 feet from center location at each site. Dave Fillucci at West Dock. Left for Seal Island. At Seal Island. locating island. Fog has burned reference at Seal set reference. Visibility causing difficulty on off, visibility unlimited. Set Island, left for Northstar to Time Event '1430 hr. 1630 hr. 1800 hr. 2000 hr. 2130 hr. 2215 hr. 2340 April hr. 21, 1987 0030 hr. 0700 hr. 1000 hr. 1030 hr. 1100 hr. 1330 hr. 1430 hr. 1455 hr. 1700 hr. 1800 hr. Unable to shoot distance between islands, mirrors off. Set target on Northstar will go to midpoint between islands. Corrected mirrors at Seal Island, located midpoint between islands. Will locate sites. Spotted polar bear at Site B, set center location. Location Site A on rough ice, location Site A off by 421 ,feet closer to Seal Island. Have located all center locations at Sites A, B, and C. Left midpoint location for West Dock. At West Dock. At Camp. End of Day. At GSL office, Anchorage. Kurt locations off geodetic benchmarks Islands. Need locations +25 feet. said that AHC added extra site Received new coordinates for Site D. said to go ahead and have GSL start road to site, and make loader from GSL to unload Dock at 1200 hrs. today. phone calls to Kurt Stangl in said need verification of site on Barren Kurt also - Site D. Also, Kurt snow blowing arrangements for a 966 Tester Drilling at West Complete phone calls. Left for West Dock. At West Dock. GSL at West Dock starting to clear road. Left West Dock with Dave Fillucci to continue surveying. At Site-C. Establish point - set-up to survey in coordinant to verify from Northstar and Seal islands. Snowblower at Site C. .Located Site D center boring. Picked up targets left for West Dock. Summary of day' located Site D, triangulated for Time E~ ,t 1915 hr. 2030 hr. 2130 hr. April 22, 1987 0630 hr. 0730 hr. 0830 hr. 0840 hr. 0910 hr. 0915 hr. 1000 hr. 1005 hr. 1230 hr. 1300 hr. 1630 hr. 1730 hr. verification of center locations of sites from Northstar and Seal Island. Remaining survey work [o be performed is verification of survey from geodetic on Barrier Islands and staking cardinal locations at each site. At West Dock. Tester Drilling equipment at West ~Dock, Tester Drilling mobilizing equipment for travel to site. At camp. Called Kurt Stangl in Anchorage. Kurt said order of priority Sites B, A, C, D. Leave camp with drill crew, will meet Dave Fillucci at West Dock at 1000 hrs. Dave Fillucci collecting coordinates for geodetic markers on Barrier Islands. At West Dock - drillers starting equipment. Drill equipment started, leave West Dock for site. Throttle cable on drill frozen. Throttle cable on drill fixed. Left steering clutch out on Nodwell. Dave Fillucci at site. Nodwell repaired continue to site from West Dock. At Site C with rolligon and pick-up truck. Drill and Nodwell still in route. Drill having problem with hydraulics. Appears to have water in fluid and freezing at splitter, causing carrier not to turn. Survey equipment loaded into rolligon. Will go to Long Island and locate geodetic Benchmark. Back at Site C. Drill not at site. Left Site C to check on drill crew. Drill approximately 1 mile on road from West Dock. Problems with hydraulics. E~cnt 1800 hr. 2105 hr. 2230 hr. 2320 hr. April 23, 1987 0600-0650 hrs. 0740 hr. 0800 hr. 0900 hr. 093'0 hr. 1010 hr. 1100 hr. 1200 hr. 1245 hr. 1400 hr, 1500 hr. 1545 hr. 1730 hr. At Site B. Locate Northstar Island. called on radio. cardinal borings. Left for Kurt Stangl at Deadhorse - Completed survey Northstar control Long Island. at Northstar turned angle from point to geodetic reference on At Mile 4 on the Nodwell shutdown site in morning. road (from Site C). Drill and and left for camp. Continue to At camp - Prudhoe Bay Hotel. Met with Kurt Stangl. At Mile 4 on ice road to site. and continue to site. Fuel equipment Left for Deadhorse to pick-up drillers at Mark Air. equipment At Mark Air. Met with Kurt Stangl at Prudhoe Bay and Dave Fillucci will be at site hours to complete survey of cardinal site A, C, and D. Hotel. Kurt around 1200 locations at Left Deadhorse for site. At Site C, drill at Site C (Driller at Site C at 1030 hr.) At Site B boring #4 (AHC B-4-87). Set up to drill. Drill will not start. Change Solenoid. Kurt Stangl and Dave Fillucci at site. Drill started, continue with set-up. Problem with wind tarp enclosure.. Need to weld spacer on top of mast to hold crown piece off of winch lines. Tarp up - drill running - No reverse on drill. Hydraulic problem. Kurt Stangl and Dave Fillucci left for Deadhorse. Surveying completed. Drill still not working. Pulled hydraulic lines, check for blockage. Time E~ -_nt 1900 hr. 1945 hr. 2045 hr. April 24, 1987 0615 hr. 0705 hr 0715 hr. 1200 hr. 1745 hr. 1800 hr. 1900 hr. 2230 hr. 2315 hr. April 25, 1987 0030 hr. 0155 hr. 0245 hr. 0630- 0730 hr. 0730 hr. 0845 hr. 1330 hr. Packed up At Site C At Prudhoe tools. Left site for - left for Deadhorse Bay Hotel. Deadhorse. on pick-up truck. Left camp for site. At Si te C. At location AHC B-4-87. drained hydraulic fluid. and in bottom of tank. Pulled Eaton Pump, Ice present in filters Kurt Stangl and John representative) at site. Kurt and hydraulic fluid to site. Ellsworth (AHC brought new pump Drill still down. Kurt and Tim Tester (Driller) call about drill. Stangl, John Ellsworth left for Deadhorse to Packed up tools, M. (Tester Drilling), jim Deadhorse. Schlegel , Fred Shoemaker White (Conetech) left for At camp. Tim Tester and M. Schlegel left camp for site to check pressure control valve on Eaton pump. At site. Took valve out of pump. Took apart assembly. Put new valve in. Drill still down. Left site for camp. At camp. END OF DAY. Discuss hydraulic problems, mechanic at site. getting a hydraulic Left for site with GSL mechanic. At Site B. Continue to work on drill Drill still down. Left for Deadhorse. rig. Time E~cnt 1430 hr. 1500 hr. 2040 hr. 2115 hr. April 26, 1987 0700 hr. 0815 hr. 0900 hr. 0920 hr. 0935 hr. 1030 hr. 1045 hr. ii50 hr. 1315 hr. 1855 hr. 2100 hr. 2150 hr. April 27, 1987 0630 hr. 0730 hr. 0900 hr. 0930 hr. 1030 hr. At Deadhorse, Prudhoe Bay Hotel. Kevin Goulet with Alaska Hydraulics to Deadhorse on evening flight. Kevin Goulet at Deadhorse. Kurt Stangl, Kevin Goulet and drillers site. arrive in left for Drill repaired. Left for site. At West Dock. Pick up Drilling generator down. At location AHC B-4-87. Prepare to drill. Ice hole cut at AHC B-4-87. 43.0 feet - water 43.5 feet - ice to mud 6.0 feet - ice EBA generator, Still checking hydraulic levels, problem pipe clamp on drill table. Started running pipe. Set up pump, samplers. Start drilling AHC B-4-87. AHC B-4-87 completed. Pipe out of hole. Pack tools, drain hydraulic tank, change filter. Hydraulic fluid replaced, filters changed. site for Deadhorse. At camp. Prudhoe Bay Hotel. END OF DAY. Tester with up Left Left camp for site. At Site B. Prepare to move. Started move to AHC B-2-87. At site AHC B-2-87. Set up to GSL mechanic onsite to repair drill. Tester generator. T~me Event 1045 hr. 1125 hr. 1135 hr. 1310 hr. 1400 hr. 1430 hr. 1550 hr. 1615 hr. 1700 hr. 1720 hr. 1815 hr. 1830 hr. 194'0 hr. April 28, 1987 0630 hr. 0730 hr. 0810 hr. 0815 hr. 0830 hr. 0920 hr. 1250 hr. Drilled ice 44.0 feet - 44.2 feet - 5.5 feet - hole at AHC B-2-87. water ice to mudline ice Started to run pipe. Started AHC B-2-87. Driller sounded hole, lost drive shoe (inside pipe). Unable to drill past drive shoe. Pull re-drill. Pipe out of hole. Moved drill ahead 1 drill hole. Complete AHC B-2-87 to 31.5 feet. Pipe out of hole. AHC B-2-87 completed. to move. Start move to AHC B-3-87. At location AHC B-3-87. Set up to drill. Drill ice hole at AHC B-3-87. Ice auger broke off - repair ice auger. Left site. At camp. Prudhoe Bay Hotel. down pipe foot. Left camp for site. At site AHC B-3-87. Prepare Drill ice hole at AHC B-3-87. 42.5 feet - water 43.0 feet - ice to mudline 7.0 feet - ice Started running pipe. Suction hose frozen. Hoses thawed. Start boring Complete borehole AHC B-3-87 to drill. AHC B-3-87. to 31.5 feet. hole and Re- Prepare flights Time Event 1330 hr. 1410 hr. 1420 hr. 1510 hr. 1545 hr. 2005 hr. 2045 hr. 2055 hr. 2140 April hr. 1987 0630 hr. 0730 hr. 0800 hr. 1030 hr. 1330 hr. 1400 hr. 1520 hr. 1650 hr. 1720 hr. 1905 hr. Pipe out of hole, AHC B-3-87 complete. Prepare to move. Started move to AHC B-1-87. Center boring at Site B. On location AHC B-1-87. Set up to drill. Drill ice hole at AHC B-1-87. 43.2 feet - water 43.5 feet - ice to mudline 6.0 feet - ice Started drilling AHC B-1-87. Drilled to 45.0 feet. Gravel to hole. Will need to re-drill using coarse. Lost drilling mud. Pipe out of hole, pump drained. for camp. Ready to leave Left for camp. At camp - Prudhoe Bay Hotel. Left camp for site. drilling mud. At site. Prepare AHC B-1-87. Drill running. Pump plumbed. on site; mixing Mud pit filled, Kurt Stangl at Stopped at Baroid to to drill. Continue At 52.0 feet. mud from 40.0 40.0 feet. pick up Borehole Drillers plumbing new pump. Started to mix mud. No mud by hand. ready to start AHC B-1-87. site. Mix second mud pit. Driller feet, drilled with water on Continue drilling AHC B-1-87. At 54.0 feet hole collapsed in upper 40.0 Unable to drill ahead. Kurt Stangl at site sample at 54.0 feet and TD. Pipe out of hole, pumps drained, drill lng cleaned up. AHC B-1-87 completed. mixer used upper feet. said mu(] Time Event 1920 hr. 2005 Apr i 1 hmo 30, 1987 0620 hr. 0735 hr. 0830 hr. 0840 hr. 1115 hr. 1345 hr. 1500 hr. 1600 hr. 1615 hr. 1620 hr. 1650 hr. 1710 hr. 1730 hr. 1820 hr. 1840 hr 1850 hr. 1905 hr. 1910 hr. 1920 hr. 2200 hr. left si[e At camp - for Deadhorse. Prudhoe Bay Hotel. Left camp for site. At site AHC Moved drill 42.6 feet - 43.0 feet - 6.0 feet - Set up to drill rig. Kurt Stangl Deadhorse to Started to Casing, Started B-1-87. Prepare to run cone. Cone on Started B. ahead 7.0 feet water ice to mudline ice (center of ice holes). run cone - plumb hydraulic ram from at site. pick up run casing ice anchor in Drill helper left site for fittings for hydraulic ram. for CPT test. place, set up for cone. to run cone rod. seafloor. Ready to CPT test at center Complete Test. Missed top CPT-B1 Site B, will have to Cone out of hole. Move rig Set casing Started CPT-B1 ready to run cone Test completed - Pulled cone rod. at Site B. start push. location CPT-B1 Site 3.0 feet of data at re-push. ahead. rod . CPT-B1 Site B. Cone out of hole - prepare to move. Night shift at site. Day shift left site returneo rolligon to Rolligon at GSL. for Deadhorse - M. Schlegel GSL in Deadhorse. Time E.~nt 1940 2130 2210 223O Ma), 0210 0320 O5OO 0600 0700 0750 0810 O85O 0920 1010 1020 1115 1130 1200 1230 1250 1320 1430 hr. hr. hr, 1 , 1987 hr. hr. hr. hr. hr. hr. hr. hr. hr. hr, hr. hr, hr. Prepare to move to CPT-B2. Move to CPT-B2. Drill ice hole at 43.0 feet - water 6.0 feet - ice CPT-B2. Start running casing. Cone at mudline. Start CPT-B2. CPT-B2 completed. Pull cone rod. CPT-B2 completed, prepare to move to On location CPT-B3. Prepare to push Crew change. Ice hole drilled 42.8 feet - water 43.2 feet - ice to mudline 6.0 feet - ice Casing set - ready to run cone. Cone on bottom. Push CPT-B3. Completed CPT-B3. Cone out of hole. Pull casing. Move to CPT-B4. at At site CPT-B4. Set up for cone. Drill ice hole at CPT-B4. 42.8 feet - water 43.2 feet - ice to mud 6.0 feet - ice Start running casing. Casing set, cone Cone at mudline. CPT-B4 completed. Cone out of hole ram leveled. Start CPT-B4. pull casing. Site B to Site Ready to move from CPT-B3. cone. CPT-B3. A · Time Event 1455 1510 1550 1645 1710 1725 1750 1815 1850 1915 2010 2130 23O0 232O May 0140 0605 0710 075O hr. hr. hr. hr. hr. hr. hr. hr. hr. hr. hr. hr. 2, 1987 hr. hr. hr. hr. At Site A. Off loaUed boring location. At CPT-A2 (Site A CPT Winds blowing +20 difficult. Drill ice hole at 43.3 feet - water 43.5 feet - ice to 6.0 feet - ice drill tools at center #2). Prepare to push cone. mph making set up very CPT-A2. mudline Casing set, ram set. Ready to run cone. Cone at mudline. Ready to start push Completed CPT-A2. Cone out of hole Tools packed up. At center boring drill tools to camp. CPT-A2. Crew change. - pull casing prepare to move. Difficulty with tarp in winds. location - will have to pick up drill as ConeTech is going in to On location AHC A-3-87. Prepare to drill. Difficulty with set up in high winds. Drilled ice hole at AHC A-3-87. 42.8 feet - water 43.1 feet - ice to mudline 7.0 feet - ice Start AHC A-3-87. Lost latch assembly on first sample, pull pipe check bit and landing ring. Drill pipe at mudline, continue Borehole AHC A-3- 87. AHC A-3-87 completed to 38.0 feet. Pull pipe. Prepare to move. Day crew at site - wait Night shift moved on to for crew change. location AHC A-2-87. Time Event O845 0900 0950 1005 1030 1330 1420 1450 1520 1615 1730 1800 1830 1905 1925 1930 May 0125 0130 0300 0420 hr. hr. hr. hr. hr. hr. hr. hr. hr. hr. hr. hr. hr. hr. 3, 1987 hr. rim. hr. Crew change at Site C. At site AHC A-2-87 Set up to drill. Difficult set up with winds +20 mph. Drill ice hole at AHC A-2-87. 42.8 feet - water 43.2 feet - ice to mudline 6.2 feet - ice Started drilling AHC A-2-87. 20.0 feet in AHC A-2-87 dropped for sampler with B rod. sampler. Fish Sampler recovered. Continue AHC A-2-87. Completed AHC A-2-87 to 33.0 feet. Pipe out of hole. Prepare to At boring location AHC A-4-87. A-4-87. Drill ice hole at AHC 43.2 feet - water 43.5 feet - ice to mud 5.5 feet - ice Started AHC A-4-87. Unable to get surface sample. not latch. Pulled pipe to check move to AHC A-4-87. Set-up to drill. Shelby tube would latch assembly. Night shift at site. Left site change. Crew change. Begin AHC A-4-87. to make crew AHC A- 4- 87 Drill pipe Drill pipe At location completed stuck at to 30.0 feet. 29.0 feet. out of hole. AHC A-1-87. Prepare to Set up to Pull pipe. move. drill. Time tven 0440 0630 0645 0720 O8O0 0830 0940 1215 1250 1325 1805 1850 1910 1920 1955 2030 222O 2245 2330 hr. hr. hr. hr. hr. hr. hr. hr. hr. hr. hr. hr. hr. hr. hr. hr. hr. Drill ice hole at AHC A-1-87. 43.0 feet - water 43.4 feet - ice to mudline 6.5 feet - ice Thawing mud pit. Day shift at site - wait for crew change. Crew change. At center boring Site A, Driller welding bit, helper water depth at AHC A-1-87. 42.6 feet - water 43.0 feet - ice to mudline 6.2 feet - ice Started AHC A-1-87. Driller cannot find cross pipe to 4 1/4-inch pipe. on string. borehole AHC A-1-87. mixing mud. Re-check over sub for Pulled pipe Sub not on drill string. Found Run pipe back in boring. At 25 feet - depth where pipe was Completed boring AHC A-1-87 to 76.5 pipe. 4 1/8-inch to see if sub in NodweT1. pulled. feet. Pipe out of hole, bit worn, no teeth on Night.shift at site. Crew change At Site A. Move drill ahead to run Ice hole drilled for CPT-A1. 43.0 feet - water 43.5 feet - ice to mudline 6.5 feet - ice bit. CPT-A1. CPT-A1 completed. Pull cone. Cone at mudline ready to push Casing set - ram set. Ready Pull CPT-A1. to run cone rod. Time Event May 0220 0230 0315 0440 0450 0605 0620 0700 0640 O740 O8OO 0830 0935 0950 1045 1130 1200 1245 1405 1920 4, 1987 hr. hr. hr. hr. hr. hr. hr. hr. nm. hr. hr. hr. hr. hr. hr. hr. hr. hr. hr. Ready to move to CPT-A2. At CPT-A2. Prepare to push Drilled ice hole at CPT-A2. 43.2 feet - water 43.5 feet - ice to mudline 7.0 feet - ice Cone at mudline. Begin push at CPT-A2 completed. Pull rod and Casing out of hole. Prepare to Move to CPT-A4. At location CPT-A4. Prepare Winos blowing - road blown followed snowblower to site. At site C. Crew change. At location CPT-A4. Drilled ice hole at CPT-A4. 42.8 feet - water 43.2 feet - ice to mud 6.0 feet - ice Cone at mudline ready to push CPT-A4 completed, Site A completed - move to Site C. Cone and casing out of hole. load up all tools for move. Move from Site A to Site C. At Site C. Set up to drill. Site C, AHC C-1-87. Drill ice hole at AHC 38.1 feet - water 38.5 feet - ice to mud 6.5 feet - ice C-1-87. Ready to drill AHC C-1-87. Crew change - 51.0 feet into cone. CPT-A2. casing. move. to push closed. CPT-A4. cone. Day shift borings and CPT Site A Center boring AHC complete - boring at C-1-87. Time Event 2230 2305 2355 Ma), 0105 O2OO 0330 0705 0730 O83O O85O 0920 1000 1240 1300 1345 1445 hr. hr. hr. 5, 1987 hmo hr. hr. hr. hr. hr. hr. hr. hr. hr. hr. hr. Sampler oropped down hole at sampler. Sampler retrieved, sample at AHC C-1-87 completed to 71.0 hole. Prepare to move. 71.0 feet. Fish for 71.0 feet. feet. Pipe out of At location AHC C-2-87. drill. Set up and prepare to Drilled ice hole at AHC C-2-87. 38.2 feet - water 38.7 feet - ice to mudline 6.5 feet - ice Begin AHC C-2-87. AHC C-2-87 completed to 32.5 feet. Pull pipe and move to Site D. Crew change. Pipe out of hole. AHC C-2-87 completed, ready _to move. Driller weld bit before dropping wind tarp enclosure. Start move to Site D. Welder on rig not working have one (1) bit left. At Site D. Boring AHC D-2-87. Drill ice hole at AHC 38.2 feet - water 38.5 feet - ice to mud 6.5 feet - ice D-2-87. Start boring AHC D-2-87. AHC D-2-87 completed to 31.5 feet. jim (Conetech) said Kurt Stangl wanted to run Site D. Pull pipe set up to run cone. White CPT at Pipe out of hole AHC D-2'87 completed. move to CPT-D2. Start At CPT-D2. Set up - prepare to push cone. winds making set up difficult. High Drill ice hole at CPT-D2. 38.5 feet - water 38.9 feet - ice to mudline 6.2 feet - ice Time Event 1505 1600 1610 1640 1705 1730 1800 1830 1920 2000 2015 2205 2220 2315 2355 May 0225 0250 0650 0935 hr. hr. hr. hr. hr. hr. hr. hr. hr. hr. hr. hr. hr. hr. 6, 1987 hr. hr. hr. hr. Casing set, ready to run Run cone rod. Cone at mudl ine, ready to CPT-D2 completed. Cone out of hole. Casing out of hole CPT-D2 move to CPT-D3. At location CPT-D3, set up Drill ice hole at CPT-D3. 37.6 feet - water 38.0 feet - ice to mud 6.0 feet - ice cone. push CPT-D2. completed. to push cone. Crew change. Casing set at CPT-D3. Cone at mudline, ready to push cone CPT-D3 completed. Pull rod. Casing out of hole CPT-D3 complete. D1 at center location. Drill ice hole at CPT-D1. 38.2 feet - water 38.8 feet - ice to mudline 6.8 feet - ice Start to run casing and cone rod at CPT-D1 completed. Pull cone rod Prepare to drill AHC D-1-87. Prepare to at CPT-D3. Move to CPT- CPT-D1. and casing. Set up at AHC D-1-87. Drill 38.2 feet - water 38.7 feet - ice to mudline 6.9 feet - ice ice hole. Begin AHC D-1-87. Crew change - at 25.0 driller shut down drill, out. feet into AHC will not start. Drill running, new starter. Continue AHC D-1-87 Starter D-1-87. T~me E~ent 1115 1200 1215 1305 1355 1430 1445 1515 1750 1805 1825 1850 1910 1930 2350 MaS 0115 0135 hr. hr. hr. hr. hr. hr. hr. hr. hr. hr. hr. hr. hr. hr. 7, 1987 hr. hr. Drill rate stopped. Pull pipe to check bit. Bit on surface. Bit plugged, pressured up and blew out latch ports on assembly. Change latch assembly. Bit on bottom. Continue AHC at site said to end borehole AHC D-1-87 completed at 52.5 Pipe out of hole, AHC D-1-87 AHC D-4-87. D-1-87. Kurt Stangl at 50 feet. feet. completed. Move to At location AHC D-4-87, prepare to drill. D-4-87. Drill ice hole at AHC 37.9 feet - water 38.3 feet - ice to mud 6.5 feet - ice Began AHC D-4-87. Completed AHC D-4-87 to 32.5 feet. Pipe out of hole. AHC D-4-87 completed. completed. Move to Site C. Left Site D for Site C, boring AHC C-4-87. Site D Drill on location AHC C-4-87. Prepare to drill. Crew change - setting up at location AHC C-4-87. Drill. ice hole at AHC C-4-87. 38.2 feet - water 38.6 feet - ice to mudline 6.3 feet - ice AHC C-4-87 completed to 32.5 feet. move to AHC C-3-87. Prepare to At location AHC C-3-87. Prepare to Drill ice hole at AHC C-3-87. 38.2 feet - water 38.8 feet - ice to mudline 6.4 feet - ice drill. Time L 0600 0705 1300 1400 2115 2330 hr. hr. hr. hr. hr. hr. AHC C-3-87 completed to 31.5 feet. Pipe out of hole. Site C completed. Field investigation completed. Begin demobilization to West Dock. Crew change. Started demobilization to West Dock. Equipment in route to West Dock. John Ellswort.h and M. Scnlegel inspected sites and performed final clean up. Drill and Nodwell at West Dock. Lynden Transport spotted flat at West Dock loading ramp. Load equipment. Personnel from EBA and Tester Drilling left Deadhorse for Anchorage. At Anchorage airport. Field program completed. APPENDIX B BOREHOLE LOGS UNIFIED SOIL CLASSIFICATIO,.. I MAJORDIVlSIONS IGROUP TYPICAL NAMES CLASSIFICATION CRITERIA I SYMBOLS ..~ Cu = 060 Die Greater than 4 ~ GW Well-graded gravels and gravel-sand ~. ~ iD30t2 "J ~ - Cc - Between 1 and 3 ~, ~ mixtures' little or no fines ~ O ~ ~ D10 x 060 "~> ~ ~ ~ d ~: Poorly-graded gravels and gravel-sand ~ '~ ~ Not meeting both criteria for GW .~ ~ Z ~ GP ~ ~ ~ ~ ~ ~ ~; O mixtures, Httle or no fines ~ ~ ~ ~ ~ 0 ~ ~ ~ ~ ~ ~ Atterberg limits plot below 'A' line Atterberg t .... ts plotting ~ Z6 ~ ~ GM Silty gravels, gravel-sand-silt mixtures ~OO ~ ~ ~ =~ or plasticity index less than 4 ,n hatched area me bor- ~ Z derl~ne cJasslf~caUons re- ~ ~ ~ ~ ~ Clayey gravels, gravel-sand clay mix- ~ ~ ~ '5 Atterberg limits plot above 'A' line qu,r,nfI use of dual ~ GC ~0 ~ ~ ~ ~ O tures ~ and plasticity index greater than 7 bols ~ '~ '~ ~ Cu = DCO/D10 Greater than 6 ~ ~ Well-graded sands and gravelly sands, ~ ~ '~ ~ ~ ~~ ~'~ ~ little or no fines ~~ ~'~ Cc DI~XDco Between 1 and 3 ~ Poorly - graded sands and gravelly ~ ~ ~ ~ ~ sands, litd ..... fines ~ SP ~ Not meeting both criteria for SW ~ .~ SM Silty sands, sand-silt mixtures = ~ ~ Atterberg limit~ plot below 'A' line Att~rherg hm~s platt,rig ~ ~ ~ ~ ~ ~ ~ -- or plasticity index less than 4 ffl hatched area are Z _ Z ~ ~ ~ derline class;hcat;ons re, ~ ~ ~ ~ ~ SC Clayey sands, sand-clay mixtures ~ ~ and plasticity index greater than 7 bols ~ ~ Atterberg limits plot above 'A' line qutrmg use of dual svm. Inorganic silts, very fine ~ands, 60 ~ ML rock flour, silty or clayey fine PLASTICITY CHART ~ sands For claim/f/cation of fine-grained~_~ .... 50 soil~ and fine fraction of coarse- *~ ~ '~ ~ Inorganic clays of Iow to medium grained loils , ~ '~ ~ '= -- Atterberg limits plotting in hatched [j CH -- 0 Z ~ ~ CL plasticity, gravelly clay~, sandy clays, ~ 40 area are borderline classifications ~ requiring use of du~l ~ymbols Z ~ ~ Organic silts and organic silty clays ~ 30 Equation of 'A' line: PI = 0.73(LL - 20) ~/ ~ [ ~ ~ ~ Inorganic silts, micaceo .... dj.to- 20 I . ~ Inorganic clay of high plasticity, < 8 ~ CH fat cllvl 4~~ ~ ML ~ OL [ ~ ~ Organic clays of medium to high 0 10 20 30 40 50 00 70 80 90 ~ OH plasticity LIQUID LIMIT Peat, muck and other highly organic *Based on the material passing the 3 in. (75 mm) sieve HIGHLY ORGANIC SOILS PT soils tASTM Designation D 2487, for identification procedure see D 2488 ICH¢~ PLASTICITY CHART j For classification of fine-grained soils and fine fraction of coarse- grained ~oils~ / ~ Atterberg limits plotting in hatched area are borderline classifications '~ requiring use of dual symbols Equation of 'A' line: Pi = 0.73(LL - 20) CL ,/' ! --r---- GROUND ICE DESCRIPTION ICE NOT VISIBLE GROUP SYMBOLS SUBGROUP DESCRIPTION SYMBOLSi Nf Poorly-bonded or friable N Nbn No excess ice, well-bonded ice, well- bonded Nbe Excess NO TE: 1, Du~l tymbo/$ are used to md/cate borderl/n¢ or m/xed /ce c/aasification$ 2. Vi¢ual est/mates of ice contents md/cared on boreho/a Io#6 ± 5% 3. Th/a sy~em of g~und ice de~r/ption ha~ been mod/- f/~ from NRC T~hn/ca/ Memo 7~, Guide to the F/eM D~r/pt/on of Permafrost for Engm~r/ng Purpo~ LEGEND Soil~ iceI VISIBLE ICE LESS THAN 50% BY VOLUME GROUP SYMBOLS SUBGROUP DESCRIPTION SYMBOLS i Vx individual ice crystals or inclusions Vc Ice coating~ on particles V Mr Randorn or irreqularly orn?nted ice formations I VISIBLE ICE GREATER THAN 50% BY VOLUME r ICE + I ·Ice with soil inclusions Soil Type ICE Ice without soil inclusions I ICE (greater than 25 mm ( 1 in.) th ckl 20 71/83 i J ! J ! I ! i i ! I ! ! I ! ! ! ! SOIL DESCRIPTION M;) - sliD/, fine--grained sand, occasional shells, loose, gray. .-.~ndy, trace of black fibrous orgomcs, occasional grovel, fine- grained ~3nd, fine--grained gravel to maximum diameter of 0.5 in., soft, -~t'~a~(~e of fine gravel, firm to stiff, grayish black. medium to dense, fine- g blackish gray. -- becoming at 6.5 ft: loose to compact, gray. GRAVEL (GP) - Sandy, trace of silt, medium-grained sond, grovel to maximum diameter of 1.5 in., dense, grayish black. - gnnvel to maximum diameter of 2 in., sub-rounded to rounded. - gravel to maximum diameter gre~ter than 2 in., becoming very dense. GROUND ICE DESCRIP~ON SP£C~U. DRILL RIG: SIMCO 4000 ~R DRILUNC WATER DEPTH 43.2 FEET SAMPLE TYPE EBA ENGINEERING CONSULTANTS LTD. EDMONTON ALBERTA DRAWING NUMBER 4667B-B- 1 BOREHOLE LOG AND LABORATORY TEST RESULTS lBOREHOLE NUMBER B-1 ] J ! J i ! ! i J i i ! i I ! J } } SAMPLE SOIL DESCRIPTION GROUND ICE I'EMP ~ ~) I.~I~ ~ UNIT TYP NO. 3 DESCRIPTIQN F ' 20 40' eO GRAVEL (GP) - sandy, trace of silt. - medium-grained sand, gravel to - maximum diameter of 2 in., very dense, grayish black. , , - grained sand, some gravel to maximum - diameter of 2 in., very dense, gray. DRILL RIG: SIMCO 4000 I SAMPLE TYPE EBA ENGINEERING CONSULTANTS LTD. BOREHOLE TESTER DRIllING I ~ S~E:LBYTUBE: J~ EDMONTON ALBERTA NUMBER WAT-r_R DEPTH 43.2 FEET r~ ~ DRAWING NUMBER B-1 ~ Si=UT SPOON ~ 4667B-B-1 P~: 2 o~ 3 BOREHOLE LOG AND LABORATORY TEST RESULTS ] ! ! ! ! ] ! ! ! ! I ! i J ! i ! ! ) SOIL DESCRIPTION CF~'TG~ - sandy, r~ealuTn: to ¢oar~e- groined sand, gravel to maximum diameter 2 in., very dense. - frozen END OF BOREHOLE 54.5 ft. GROUND ICE DESCRIPTION Nbn DRILL RIG: SIMCO 4000 TESTER DRIllING WATER DEPTH 45.2 FEET SAMPLE TYPE EBA ENGINEERING CONSULTANTS LTD. BOREHOLE rTT~ S~ELBY TUa~ ~ EDMONTON ALBERTA NUMBER ~ FTr'l DRAWING NUMBER B- ~ I~ SPUT SPOON ~ 4667B-B--1 P~C_,[ 3 o~ 3 BOREHOLE LOG AND LABORATORY TEST RESULTS | } J ! i I ! I i i i I I } SOIL DESCRIPTION - silty, occasional shells, groined sand, loose. SAMPLE - sandy, trace of black fibrous organics, fine sand, soft. - occasional shells, fibrous organics becoming brown, interbedded with fine sand, grey, organic odor. silty, trace of organics in sand portion, fine- groined sand, interbedded seams of black fibrous organics from 2 in. to 6 in. in depth, loose, blackish gray. GRAVEL (G--~-SP---~- sandy, medium- to coarse grained sand, gravel sizes to 1.5 in. rounded to sub-rounded grovel. - grovel sizes to 2.0 in. ~R~V~L-[G~) - sandy, grovels to 2.0 in., sub-rounded to rounded gravel, medium- to coarse-groined sand, very dense, gray. .ou.o i3hs DRILL RIG: SIMCO 4000 TESTER DRIllING WATER DEPTH 44.0 FEET t~onsol aL Cup_, DSS SAMPLE TYpE EBA ENGINEERING CONSULTANTS LTD. BOREHOLE rTTT] SHam, TUaE ~ EDMONTON ALBERTA , NUMBER [~ r-T'l-] DRAWlNG NUMBER 8-2 ~ SPLrr SPOON ~ 4667 B-B-2 J P~E: ~ o~ 2 BOREHOLE LOG AND LABORATORY TEST RESULTS J ! ] J ! ! ! ! ! J ! ) ] ] ] ! } . ! ] SAMPLE SOIL DESCRIPTION GROUND ICE DI~SCRIPTION GRAVEL (GP) - sandy, gravels to 2.0 in., sub-rounded to rounded gravel, medium- to coarse--grained sand, very dense0 gray. - trace of fine sand. - sand content increasing. END OF BOREHOLE 31.5 ft. DRILL RIG: SIMCO 4000 TESTER DRILLING WATER DEPTH 44.0 FEET SAMPLE TYPE sPLrr sPoo. FRq EBA ENGINEERING CONSULTANTS LTD. EDMONTON ALBERTA DRAWING NUMBER 4667 8-8-2 BOREHOLE NUMBER B-2 P~2 OF2 BOREHOLE LOG AND LABORATORY TEST RESULTS J ! I J ! ! ! ! ! J ! ] ! ~ ! ] ! } ! J ~pIF' SOIL DESCRIPTION - silty, occasional shells, occasmna ravel, fine--grained sand, gravel 0.5 in. in diameter, - silty, some gravel, trace of organmcs, fine- to medium grained gravel to 0,5 in, in dlameter, medium - sandy, some gn3vel, b'ace of brown fibrous organics, fine-grained sand, gravel sizes to 1.0 in. in trace of g sand, gravel sizes to 1.0 -occasional shell fragments, occamona gravel, fine- to medium- ' sand ravel sizes to 0.5 in. GRAVEL sandy, gravel sizes to 1.5 in. in rounded to sub- rounded, medium- to coarse-grained sand, dense, gray. - driller noted clay layer. - increasing sand content, maximum gravel sizes to 1.0 in. in diameter. - decreasing sand content, maximum gravel sizes to 2.0 in. in diameter, becoming very dense. GROUND ICE DESCRIPTION DRILL RI(;: $1MCO 4000 TESTER DRIllING WATER DEPTH 42.5 FEi'T SAMPLE TYPE EBA ENGINEERING CONSULTANTS LTD. EDMONTON ALBERTA DRAWING NUMBER 4667B-B-3 BOREHOLE NUMBER B-3 PAGE: 10~2 BOREHOLE LOG AND LABORATORY TEST RESULTS ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! I ! ] SOIL DESCRIPTION GROUND ICE DESCRIPTION SAMPLE ~VEL (GP) - sandy, grovel sizes to 2.0 in. in diameter, rounded to sub- rounded, medium- to coarse-grained sand, very dense, gn3y. - increosing grovel sizes to greater than 2.5 in. in diameter. END OF BOREHOLE 31.5 ft. DRILL RIG: SIMCO 4000 TESTER DRILLING WATER DEPTH 42.5 FEET SAMPLE TYPE EBA EJ~IGIN-F_ERING CONSULTANTS LTD. EDMONTON ALBERTA DRAWING NUMBER 4667B-B-5 8OREHOLE NUMBER B-3 PACE2~2 BOREHOLE LOG AND LABORATORY TEST RESULTS i i ! J ] J ! NOR'mST~/~ SOIL DESCRIPTION D (SM) - s~ty, occasional shells, occasional gravel, grovel sizes to 0.5 in, in diameter, medium to dense, ~sa~"'dy, ~ce'~'f bilk ~"~rou'~' organics, fine- to medium-grained sand, gray. - sil.bj, occasional fine gravel, medlum-gr~ined sand, gray. GRAVEL ~GP) - sandy, trace of silt, medium- to c. oarse-grained sand, gravel claets .(chert/dolomite, orthoclase feldspar) to 1.0 in. in diameter, medium to dense, gray. - gravel sizes to 2.0 in. in diameter. some silt, trace of organics, occasional shell fragments, a~ravel sizes to 0.5 in. in diameter, Tine-- to medium-grained sand, disseminated L _ocg ~zD iG!.,_g r~y~_ GRAVEL (GP) - sandy, trace of silt, medium- to coarse-gr~ined sand with a trace of fines, gravel sizes to 1.5 in. in diameter, dense, gray. - gravel sizes to 2.0 in. in diameter, sand fines disappear, becoming very dense. DRILL RI(;: SIMCO 4000 TESTER DRIllING WATER DEPTH 43.0 FEET GROUND ICE DESCRIPTION EBA ENGINEERING CONSULTANTS LTD. EDMONTON ALBERTA SAMPLE TYPE BOREHOLE LOG AND LABORATORY TEST RESULTS DRAWING NUMBER 4667B-B-4 BOREHOLE NUMBER B-4 PAGE1 (~2 ] ] ] I ] ! ! ] I ! ] ] 1 I 1~7 ~ ~ ~110N ,JaliE:RAZ:)~ ~ CORPORATION S~J~PL~I SOIL DESCRIPTION GRAVEL (Gl3) - sandy, trace of silt, medium- to coarse-gn3ined sand, grovel sizes to 2.0 in.in diameter, very dense, gray. - sand becoming coarse, grovel sizes to 2.5 in. in diameter, sub-rounded to rounded closts. - trace of medium- to coarse-grained sand. ENO OF BOREHOLE ;36.5 ft. GROUND DESCRIPTION DRILL RIG: SIMCO 4000 TESTER DRIllING WATER DEPTH 45.0 FEET FFFn ~u~ ~sam PL~z~PE I~ sPu*r SPOON CR-] EBA ENGINEERING CONSULTANTS LTD. EDMONTON ALBERTA DRAWING NUMBER 4667B-B-4 BORE'HOLE NUMBER B-4 PAGE2 OF2 BOREHOLE LOG AND LABORATORY TEST RESULTS APPENDIX C CONE PENETRATION TEST RESULTS J ! I I I ! I } ! ! ] J ] ] ! ] J ! CONTRACTOR. ConeTm¢ SZTE. PRUOHOE BAY AK DATE, 04/30/87 :lB, 58 CONE, 10 TOH IqO. 174.. Ih'qG Page No, ] / 1 CPT NO, Eldll CENTRE I-- O_ W 1,$ 0 C~ SLEEVE FRICTION O0 0 I 2.5 FRICTIOH RATIO PORE PRESSURE RFCD U(& lO -lO 4O g~p'l:.~ Incrmmun[ , .05 m DIFFERENTIAL P.P. RAT]O iLl/Ut -.2 .8 Max Dopth , 1.9 m I HTERPRETED PROFILE 1 } I I ] ] ] ! ! ! ] J ] i ] i i } CONTRACTOR. Con,aTmo SZTE, PRUDHOE BAY AK. DATE. 05/0:1/87 02. 20 CONE. ] 0 ToNr,,tO. ]'74.. P~..qm No, Z ! ! CPT NO, El#2 NE 4.: CONE ~I~ SLEEVE FRICTION FRJCTION RATJO PORE PRESSI,.I~E F. (t.tr) RIP (Y,,) U (-. oF' 100 0 2.5 0 10 -lO 0 40 I · · DJFFERENTJAL P.P. RATJO AU/O% -.20 INTERPRETED ~,ILE Dop%h Inor'mmm~'~% , .0.5 m H,:~x D,apth , 2. 95 m ] ] ! J ] J i J J ! ! ! .. J I I ] ! ! EE .A. CONTRACTOR~ SZTE~ PRUDHOE BAY AK. DATE, 05/01/67 DO, 17 CONE, ZO ToriNO. Z74.,,, P,',gm No, Z / 1 CPT NO, B83 SOUTH [. E 1.5 gt FRICTION FRICTION RATIO PORE Ct, a~ R,F' O0 U (a. 2.5 O10 -10 151 tsf ----~ 135 tsf ~ · · & & I & & · · · Omp~h lncremen~ , .OS m DIFFERENTIAL P.P. RATIO & U/Or. -.2 0 .6 Mc~x Oel:~h , ]. 45 m ! I ! 1 ! I I I I I I I i ! i I I ! I CONTRACTORs ConmTmo $!TI;, PRtJOHO£ BAY AK. DATE, 05/0!/87 !2,52 CONEs 10 TONNO..174.. CPT NOs B#4 NORTH YEST L, 0 ~. W 0 155 tsf --~ 153 tsf --~ SLEE'YE fRICTION FRICTIOH RATIO PORE PRE~ DIFF'E:K"E~TIAL P.P. IN~£TED F. (tel) Rf (X,J U Ga. of .crta'") RATIO AU/I~ PROFILE, 2.5 0 lO -lO -.2 .8 I APPENDIX D SUMMARY OF LABORATORY TEST RESULTS AND GRAIN SIZE DISTRIBUTIONS i ! ! ] I I I ! I ! ! ! ! I I I ! ] } Depth (feet) "Sample Photographed B-1 0.0 - 1.5 3.0 - 3.5 7.5 - 8.5 17.0- 18.0 22.0- 23.0 27.0- 2C, 37.0- 38.0 47.0 - 48.5 54.0 - 54.5 B-2 _ Q. 0 - 2_..O 3.0 - 4.5 :5, Q- 7.5 10.0- 11.0 15.0 - 16.0 25.0 - 26.0 30.0 - 31.0 LEGEND AND NOTES B - ~g Sample G - Gas Sample L - Liner Sample P - I~$ton Sample NR - No Recovery NS · No Sample Remaining C - Frozen Core PW - Porewater Sample T - Sample Stored in Tube W - Waxed Sample RC * Radiocarbon sample MV * Minivane FC - Fall Cone TV * Torvane PV - Pilcon Vane RV - Remote Vane SUMMARY OF TEST RESULTS LIMITS GRAIN SIZE DISTRIBUTION UU - Unconsolidated Undrained Triaxial O -.Organic Content UUp- UU Triaxial with Pore S - Salinity Pressure Measurements TS - Thaw Strain CU - Consolidated Undrained Triaxial SG - Specific Gravity CUp - CU Triaxial with Pore Pres~ureMea~ .... ants DSS - Direct Simple Shear CD - Consolidated Drained Triaxial SHEAR STRENGTH Consistency CONSOLIDATION CHARACTER ISTICS Project Number: 0501-4667B ReviewedB¥: D.R. Williams P.Eng. 1 3 Page~ of __ 2143/3719 I ! ! ] } I i ! I ! I ! ! ! } I ! J ] Depth (feet} 'Sample Photographed 0.0 - 1.0 1.0 - 1.5 3.4 - 3.6 3.6 - 5.0 5.0 - 5.5 7.0 - 8.0 15.0- 16.5' 20.0- 20.5 25.0- 26.0 30.0 - 31.O SUMMARY OF TEST RESULTS LIMITS GRAIN SIZE DISTRIBUTION SHEAR STRENGTH Consistency CONSOLIDATION CHARACTERISTICS LEGEND AND NOTES B - Bag Sample G - Ga~ Sample L - Liner Sample P * Piston Sample NR No Recovery NS - No Sample Remaining C - Frozen Core PW - Porewater Sample T - Sample Stored in Tube W * ~Naxed Sample RC - Radiocarbon sample MV - Minivane FC - Fall Cone TV - Torvane PV - Pilcon Vane RV - Remote Vane UU - Unconsolidated Undrained Triaxial O - Organic Content UUp- UU Triaxial with Pore S - Salinity Pressure Measurements TS - Thaw Strain CU - Consolidated Undrained Triaxial SG - Specific Grawty CUp - CU Triaxial with Pore PressureMea~urement$ DSS -Direct Simple Shear CD - Consolidated Drained Triaxial Prolect Number: 0501-4667B Reviewed By:. D .R. Wi 11 iams P.Eng. 2 3 Page__ of __ 2143 3179 I ! ! I ! J ! ! ! ! ] ! ! ! ! J ! ! ] Depth (feet) "Sample Photographed B-4 0.0 - 1.5 SUMMARY OF TEST RESULTS LIMITS GRAIN SIZE DISTRIBUTION SHEAR STRENGTH CONSOLIDATION CHARACTERISTICS Consistency LEGEND/~ND NOTES B - Bag Sample G - G~s Sample L * Liner Sample P Pist~n Sample No Recovery NS - No Sample Remaimng C - Frozen Core PW - Porewater Sample T - Sample Stored in Tube W Waxed Sample Radiocarbon sample MV - Minivane FC - Fall Cone TV - Torvane PV - Pdcon Vane RV - Remote Vane UU - Unconsolidated Undrained Triaxial O - Organic Content UUp- UU Triaxial with Pore S - Salinity Pressure Measurement~ TS - Thaw Strain CU · Consolidated Undrained Triax~al SC;* Specil*c (~ravlly CUp - CU Tr~axial with Pore tsDSS Direct 5hear Pre~ure ~ ...... - ~lmp~e CD - ComolJdated Drained TriaxJal Project Number: 0501-4667B D.R. Williams Reviewed By: P.Eng. Page~ ~143'3779 I-,f,,. I I F v i ~.~.. I 841 i o.' 1 lO0 9O 8O 7O ~: 60 '- 50 " 40 30 2O 10 GRAIN SIZE CURVES U.S. STANDARD SIEVE NUMBERS U.S. STANDARD SIEVE OPENINGS IN Ir¢CHES HYDROMETER 4o ~ L 7o ~ CURVE BORING NO. PENETRATION, Ft. I~TER~AL ~ BI 3.0 100 7O 60 50 40 ~0 I GRAIN SIZE CURVES U.S. STANDARD SIEVE NUMBERS U.S STANDARD SIEVE OP[NINGS IN INCHES HYDROMETER 11//2 1 3~ 1~ 3~1 th 4 6 8 10 14 16 20 30 40 50 70 100 140 200 0 [[[' ~]' "' ]']] ''"']'[]'1 """"lrt[[ ' ~o III 111t II1 ~, 111 II1 III1 I111 1~ 50 10 5 1.0 0.5 0.1 0.05 0.01 0.~5 Grain Size In Millimeters 2O 40 50 7o 0.001 GRAVEL SAND I SILT or CLAY Coarse I Fine Coarse I Medium I Fine CURVE BORING NO. PENETRATION. Ft. MATERIAL lO0 90 80 70 ~ 50 30 20 10 I I I GRAIN SIZE CURVES U.S. STANDARD SIEVE NUMBERS U.S, STANDARD SIEVE OPENINGS IN INCHES 3 2 11,/2 1 1/~ 3/~ 1/~ 4 6 8 10 14 16 20 30 40 50 70 100 140 200 HYDROMETER 100 50 10 5 1.0 0.5 0.1 0.05 0.01 0.005 Grain Size In Millimeters 10 20 30 40 ~ 50 ~ 70 ~' 80 100 0.001 CURVE BORING NO. PENETRATION. Ft. N^TERI^L lO0 90 80 GRAIN SIZE CURVES 70 50 40 30 20 10 U.S. STANDARD SIEVE NUMBERS U.S. STANOARD SIEVE OI~.NINGS IN INCHES HYDROMETER 0 100 0 10 20 30 50 10 5 1.0 0.5 0.1 0.05 0.01 0.005 40 50 70 100 0.001 Grain Size In Millimeters GRAVEL ! SAND Coarse I Fine Coarse ! Medium ! Fine SILT or CLAY CURVE BORING NO. PENETRATION. Ft. MATERIAL ~ ~ 8l 37.0 GRAIN SIZE CURVES 7O 60 5O 40 30 U.S. STANDARD SIEVE NUMBERS U.S. STANDARD SIEVE OPeNINgS IN INCHES HYDROMETER 100 ' 3 2 1 'y4 72 ~ 7'4 4 6 810 1416 20 30 40 50 70 100 I [ I I I I' I I i i I II I I I I II II I I I I 0 90 10 * 11I _ III 0 I I I ! I ! I I I ! I I I I I I I I I II I 1 100 50 10 5 1.0 0.5 0.1 0.05 0.01 0.005 Grain Size In Millimeters 40 ~ 5o 70 ~' 0.001 CURVE BORING NO. PENETRATION. Ft. MATERIAL ,., ,,., ,.., B! 54.0 I GRAIN SIZE CURVES 70 ~ 60 $ 5O '~ 4O 100 - U.S. STANDARD SIEVE NUMBERS U.S. STANDARD SIEVE OPENINGS IN INCHES HYDROMETER 3 2 1'/~ 3/~ % 3~ % 4 6 8 10 1416 20 30 40 50 70 100 140 200 0 ~o ~'-., 111 '~---~ =~~ ~-, I11 ~o 111 100 50 10 5 1.0 0.5 0.1 0.05 0.01 0.005 Grain Size In Millimeters 30 40 70 0.00~ GRAVEL SAND ! SILT or CLAY 1 Coarse ! Fine Coarse ] Medium I Fine CURVE BORING NO. PENETRATION, Ft. MATERIAL ,-, ~ B2 20.0 GRAIN SIZE CURVES U.S. STANDARD SIEVE NUMBERS U.S. STANDARD SIEVE OI~NINGS IN INCHES 3 2 11/~ 3//4 1//2 3~1 1/~ 4 6 8 10 14 16 20 30 40 50 70 100 140 200 HYDROMETER 9O 10 8O 2O 7O 60 5o aO 30 3O 40 5o 7o 2O 10 0 100 CURVE 50 - 10 5 GRAVEL Coarse I Fine BORING NO. 1.0 0.5 0.1 Grain Size In Millimeters SAND Medium I Fine PENETRATION. Ft. 0.05 0.01 0.005 SILT or CLAY MATERIAL i100 0.001 ~ ,,., -,.,- B2 25.0 100 GRAIN SIZE CURVES U.S. STANDARD SIEVE NUMBERS US STANDARD SIEVE OPENINGS IN INCHES 3 2 1~/~ 1 3/~ ~//2 3~1 ~/~ 4 6 8 10 14 16 20 30 50 70 100 140 200 HYDROMETER I 10 80 70 ~: 60 ~ 5O 30 30 40 ~ so 7o ~' 20 10 0 100 50 10 5 1.0 0.5 0.1 0.05 Grain Size In Millimeters GRAVEL Coarse [ Fine SAND Medium i Fine 0.01 0.005 SILT or CLAY CURVE BORING NO. PENETRATION, Ft. MATERIAL B3 0.0 100 0.001 I I I __ I_ I _ ! ~,n J _ J I J ~,-' I's4. J o.. u.s. STANOARO S, EVE NUMBERS GRAIN SIZE CURVES U.S. STANDARD SIEVE OPENIN(tS IN INCHES 1/~ 3/~ 1/~ 4 6 8 1'0 14 16 20 30 40 50 70 100 140 200 HYDROMETER III 90 10 80 20 70 ~: 60 ~ aO $0 30 .-. 40 ~' 5o 70 ~' 20 10 0 100 50 10 5 GRAVEL Coarse J Fine CURVE BORING NO. B3 1.0 0.5 0.1 Grain Size In Millimeters 0.05 0.01 0.005 SAND Medium J Fine SILT or CLAY PENETRATION, Ft. 3.6 MATERIAL 100 0.001 70 60 50 o~ ~ ~0 ~0 GRAIN SIZE CURVES U.S. STANDARD SIEVE NUMBERS U.S. STANDARD SIEVE OPENINGS IN INCHES HYDROMETER ~ 11 140 2O0 100 3 2 ~4 72 ,~ y4 4 6 8 10 14 16 20 30 40 50 70 100 O0 10 80 20 , \ 20 ~" 80 10 100 50 10 5 1.0 0.5 0.1 0.05 0.01 0.005 0.001 Grain Size In Millimeters GRAVEL [ SAND Coarse I Fine Coarse I Medium Fine SILT or CLAY 40 ~ so [ CURVE BORING NO. PENETRATION. Ft. MATERIAL · ., 0 83 7.0 II IIII IIIII I II IIII I II I I I I 100 70 ~ 60 30 GRAIN SIZE CURVES U.S. STANDAnD SIEVE NUIdBER$ . U.S. STANDARD SIEVE OPENINGS IN INCHES HYDROMETEFI 3 2 1 3/~ 1/2 3~ 1/~ 4 6 B 10 14 16 20 30 40 50 70 100 140 200 0 90 !) 10 80 ~ , 20 ___ \ 30 \ , , \ _ 20 \ · ~00 50 ]0 5 ~.0 0.5 0.~ ~ 0.05 0.0~ 0.~5 0.~ ~rain Gize In Millimeters CURVE BORING NO. PENETRATION. Ft. MATERIAL 5o ) 70 ~' I II I 100 90 GRAIN SIZE CURVES 80 70 60 50 40 30 20 10 U.S. STANDARD SIEVE NUMBERS U.S. STANDARD SIEVE OPENINGS IN INCHES HYDROMETER 0 100 0 10 20 30 50 10 5 1.0 0.5 40 50 70 0.1 0.05 0.01 0.005 100 0.001 Grain Size In Millimeters GRAVEL { SAND Coarse I Fine Coarse I Medium I Fine SILT or CLAY CURVE BORING NO. PENETRATION. Ft. MATERIAL I-,, ! _ i _ ] __ ! c_.. ! ....! 100 7O 60 5O 40 30 GRAIN SIZE CURVES U.S. STANDARD SIEVE NUMeERS U S STANDARD SIEVE OPENIN(3S IN INCHES HYDROMETER 3 2 11//2 3~ 1/~ 3/{I 1/~ 4 6 8 10 14 16 20 30 40 50 70 100 140 200 0 10 "'""' '-E~... -~"~E~-... 90 100 50 10 5 1.0 0.5 0.1 0.05 0.01 0.005 0.001 Grain Size In Millimeters GRAVEL SAND I SILT or CLAY Coarse [ Fine Coarse ! Medium I Fine CURVE BORING NO. PENETRATION. Ft. MATERIAL ,.., ,.., ,.., B4 6.0 I I I GRAIN SIZE CURVES 100 90 80 70 60 50 aO 30 20 10 0 100 U.S. STA~ARD $1EV~ NUMBERS U.S. STANDARD SIEVE OPENINQ$ IN INCHES 3 2 11/~ 3/~ 1/~ 3/~ 1/~ 4 6 8 10 14 16 20 30 40 50 70 100 140 200 HYDROMETER Ill I11 50 10 5 1.0 0.5 0.1 0.05 0.01 0.005 Grain Size In Millimeters 10 20 30 40 Coarse I Fine Coarse I Medium I Fine SILT or CLAY 70 '~ CURVE BORING NO. PENETRATION. Ft. MATERIAL 100 0.001 -., ,.., ,.., B4 itO. O 100 90 80 70 GRAIN SIZE CURVES I III 60 50 40 30 20 10 U.S. STANDARD SIEVE NUMBERS U.S. STANDARD SIEVE OPENINGS IN INCHES HYDROMETER 0 100 140 2O0 3 1~2 1 "X4 ~2 "~ V'4 4 6 810 1416 20 30 40 50 70 100 ' X'_ I , , I Ii 11 I , 1 I , ! I i , I I i , i 1 I , , __ __ \ \ , ! ~ i I I [I I ~ I I I I i I I i ~ r't--~... : , 10 20 30 40 50 10 5 1.0 0.5 0.1 50 70 0.05 0.01 0.005 100 0.001 Grain Size In Millimeters GRAVEL i SAND Coarse I Fine Coarse I Medium I Fine SILT or CLAY CURVE BORING NO. PENETRATION. Ft. MATERIAL B4 25.0 APPENDIX E SHEAR STRENGTH TEST RESULTS APPENDIX E SHEAR STRENGTH TEST RESULTS E.1 CONSOLIDATED-UNDRAINED TRIAXIAL TESTS WITH PORE PRESSURE MEASUREMENT A consolidated-undrained (CUp) triaxlal test with pore pressure measurements was performed on one sample. The test results are presented on Table E.1 and Figure E.1, in the following pages. A 2.9 inch diameter sample was trimmed to a height of 5.4 inches and placed in a tr£axial cell and jacketed. A pore pressure response test was carried out. If further saturation was required, back pressure was applied to the sample until a minimum B value of 0.95 was obtained. Then, the sample was consolidated isotropically under the specified confining pressure. During consolidation, the volume change of the sample was recorded and plotted against the square root of time. This plot was used to determine when primary consolidation had ended. Once consolidation was complete, drainage was shut off. Samples were sheared at a controlled rate of strain of 0.04% per minute. Failure was defined as the condition of peak stress ratio (peak obliquity). E.2 CONSOLIDATED CONSTANT VOLUME DIRECT SIMPLE SHEAR TESTS Direct simple shear tests were performed on two samples. The tests were performed as consolidated, drained, constant volume tests, which yield result equivalent to consolidated undrained tests. The test results are presented as Tables E2 and E3, and Figures E2 and E3, in the following pages. Samples were trimmed to a diameter of 2.7 inches and a height of 0.8 inches, and enclosed in a membrane surrounded by annular plates that would permit the imposition of shear strains but not lateral normal strains. A prescribed vertical consolidation stress was applied and sustained until the end of primary consolidation. Following consolidation, the sample was sheared laterally at a rate of 0.07% per minute, with drainage permitted. The vertical effective stress was varied automatically to maintain constant sample height. The tests continued to a shear strength of at least 25%. Strn 0.00 .12 .16 .29 .43 .57 .70 .84 .98 1.12 1.27 1.40 1.57 1.67 1.81 1.95 2.09 2.22 2,36 2.50 2,64 2.78 2.92 3.06 3.20 3,34 3.48 3.62 3.76 3.90 4.04 4,18 4.33 4.47 4.62 4.76 4.91 5.06 5.20 sl-s3 (ksf) 0.000 .050 ,.077 ,160 .233' .296 ,345 ,384 .414 .436 .455 .468 .480 .490 .499 .511 .524 .536 .548 ,561 .573 .585 ,597 ,.606 .618 .627 .639 .648 ,656 ,668 .677 .685 .697 .706 .717 .726 .737 .749 .764 TABLE E. 1 CONSOLIDATED UNDRAINED TRIAXIAL TEST DATA Date Computed ......... 11:23 AM Date Tested ........... 87-06-02 Job Number ............ 0501-4667 Test Hole,. DePth.,.,.. Test Number Strain rate Cell Pressu Back Pressu Parameter B THU., ....... .... AHC-B-2-87 .....,,.... 3.0 - 4.5 ft. ... ...... .. CIU-1 (% Per min) .039 re..(ksf),, 1,94 re,,(ksf),. 1,4 ... ........ 1,00 Water Content Wet Densit~ Dry 'Density INITIAL FINAL (%) 43. 38. (Pcf) 108,9 115.1 (Pcf) 76.4 83.1 TPore EPore ParA VolCh sl/s3 s-s/2 sfs/2 (ksf) (ksf) (%) (ksf) (ksf) (ksf) 1.44 0.0000 1.48 .0406 1.50 .0544 1.54 ,1025 1.58 ,1441 1.62 .1804 1.65 .2103 1.68 .2348 1.69 .2540 1.71 .2700 1.72 .2828 1.73 .2924 1.74 .3020 1.75 .3063 1.75 .3117 1.76 .3159 1.76 .3202 1.76 .3223 1.77 .3245 1.77 .3255 1.77 .3277 1.77 .3287 1.77 .3287 1.77 .3298 1.77 .3309 1.77 .3309 1.77 .3309 1.77 .3309 1.77 .3309 1.77 .3298 1.77 ,3298 1.77 .3287 1.77 .3287 1,77 .3277 1,77 .3266 1.77 ,3255 1.77 .3245 1.76 .3234 1.76 .3223 .00 0.000 1.000 0.000 .501 .81 0.000 1.109 .025 .486 .71 0.000 1.172 .038 .485 .64 0.000 1,401 .080 ,479 .62 0.000 1.652 .116 .474 .61 0.000 1.922 .148 .469 · 61 0.000 2,186 .173 ,464 .61 0.000 2.443 .192 .459 .61 0.000 2.674 .207 .454 .62 0.000 2.887 .218 .449 .62 0.000 3.086 .228 .446 .62 0.000 3.242 .234 ,443 .63 0,000 3.412 ,240 .439 .63 0.000 3.513 .245 .440 .62 0.000 3,632 .249 .439 .62 0.000 3.760 .256 ,441 .61 0.000 3.893 .262 ,443 .60 0.000 3,996 ,268 .447 ,59 0.000 4,102 .274 .451 .58 0,000 4,191 .280 .456 ,57 0.000 4,300 ,286 .460 .56 0.000 4.391 ,292 .465 · 55 0.000 4.462 ,299 .471 .54 0.000 4.535 ,303 .474 .54 0.000 4,628 .309 .479 .53 0.000 4,680 .313 .484 ,52 0,000 4.750 ,319 .490 .51 0.000 4.802 ,324 .494 .50 0.000 4,853 .328 ,498 .49 0.000 4.898 .334 ,505 .49 0,000 4.949 .338 ,510 .48 0.000 4.974 .343 .515 .47 0,000 5.042 ,349 .521 .46 0.000 5.066 ,353 .526 .46 0.000 5.108 .359 .533 .45 0.000 5.132 ,363 .539 ,44 0.000 5.172 .369 .545 .43 0.000 5.212 .374 ,552 .42 0.000 5.269 ,382 .561 2 JULY, 1987 Strn (%) si-s3 (ksf) TABLE E.1 (cont'd) Test Hole ............. AHC-B-2-87 DePth ................. 3.0 - 4.5 ft. Test Number ........... CIU-1 TPore EPore Para VolCh sl/s3 (ksf) <ksf) (%) (ksf) s-s/2 (ksf) s+s/2 (ksf) 5.35 5,49 5.63 5.78 5,92 6.07 6.21 6.36 6.51 6.66 6.80 6.95 7,10 7.25 7.40 7.55 .775 .787 .798 .806 .814 .823 .831 .836 .844 ,849 .857 .862 .869 .877 ,885 .893 1.76 .3213 ,41 0.000 5.308 1.76 .3202 .41 0,000 5.346 1,76 .3191 .40 0.000 5.383 1.76 .3181 .39 0.000 5.402 1.76 .3170 ,39 0.000 5.421 1.76 .3170 .39 0.000 5,466 1.76 .3159 .38 0.000 5,484 1.76 .3159 ,38 0.000 5.511 1.76 .3159 .37 0.000 5.554 1.76 ,3159 .37 0.000 5,580 1.76 .3149 .37 0.000 5.597 1,75 .3138 ,36 0.000 5.597 1,75 .3117 ,36 0.000 5.587 1,75 ,3085 ,35 0.000 5,552 1.75 .3063 .35 0.000 5.542 1.74 .3031 .34 0.000 5.509 ,388 .393 ,399 .403 .407 .411 .415 ,418 .422 ,424 .428 .431 .435 .439 .443 .447 .567 ,574 ,581 .586 .591 ,596 .601 .603 .607 .610 ,615 ,618 .624 .631 ,637 .645 Tmst no. CIU-1 .50 Dmy dmns. (pcF) 83. 10 O~ 0 0 [1. 0 X W 1.6 1.2 .8 .4 .0 .4 .2 0.0 -.2 -.4 I , 1 10 15 Axial Strain I , 1 20 25 (%) - I I , I I J 0 5 10 15 Axial Strain 20 (%) 25 CONSOLIDATED UNDRAINED TRIAXIAL TEST FIGURE E. Io @.0 7.0 5. D Test no. £IU-1 .50 1. O O 5 lO 15 Axiol Stroin .8 Ory dens. (pc?) 83. 10 20 25 .8 .4 .2 ! I I 'O0. o .2 .B .4 .8 (Si' +SS')/2 I , 1.0 1.2 CONSOLIDATED UNDRAINED TRIAXIAL TEST FIGURE E. lb TABLE E. 2 SIMPLE SHEAR TEST DATA Date Tested ........... 87-06-04 Job Number..,. .... ..,. 0501-4667 Test Hole..,. ......... AHC-B-2-87 DePth ..... . .... ....... 3.0 - 4.5 ft. Test Number ........... SS-1 Strain rate (% Per min) .072 Normal Stress,,(ksf),, 2,00 (6ye) INITIAL FINAL Water Content (%) 53. 39. Wet Densit~ <Per) 104.4 N/A gr~ Densit~ (Per) 68.2 N/A E Th ElaPsed Shear Shear Time Strain Stress (mir,) (%) (ksf) 6v Vert. Delta Th/6v Modulus Delta6v Stress 6v Th/E (ksf) (ksf) (ksf) 6v¢ Th 6ye Modulus 6vc O. 0,00 0.000 4. .10 .094 7. .21 .128 9. ,33 .159 10, ,46 ,188 12, ,58 ,215 15. ,72 .242 16, ,86 ,265 18, 1,00 .287 20. 1.15 .307 23. 1.30 .326 24. 1.45 .343 26. 1.60 .359 28. 1.75 .374 31. 1.90 .388 32. 2.05 .40O 34. 2.20 .411 37. 2.35 .4~ 39. 2,50 .431 40. 2.65 .441 42. 2.80 .449 45. 2.96 .456 46. 3.11 ,464 48, 3.26 .470 50. 3.40 .477 53. 3.56 ,484 54, 3.70 .489 56. 3.85 ,496 58. 4,00 .502 61, 4,15 ,507 62. 4,30 .513 64. 4.45 ,517 67. 4.61 .521 69. 4.76 .525 70. 4.91 .528 72. 5.07 ,532 75. 5.23 .534 76. 5,38 .538 78. 5.54 .541 2.000 0,000 0.0000 0.00 0.000 2.014 .013 ,0466 98.51 .007 2,003 .003 .0638 60.18 .001 1.990 -.011 .0800 47.85 -.OOS 1.976 -.024 .0950 41,11 -.012 1,963 -,038 ,1095 36.76 -,019 1,949 -.051 .1242 33.67 -,026 1.933 -.067 .1372 30,89 -.034 1.920 -.081 .1495 28.64 -.040 1,906 -.094 .1612 26,78 -.047 1.890 -,110 .1727 25.14 -.055 1,877 -,124 ,1826 23.67 -.062 1.863 -.137 .1927 22.46 -.069 1,847 -,153 ,2024 21,39 -.077 1.831 -,169 .2117 20.39 -.085 1.812 -.188 ,2206 19.50 -.094 1,793 -.207 .2290 18.66 -.104 1.772 -.229 .2379 17.92 -.114 1.750 -.250 .2463 17.22 -.125 1.726 -.274 .2552 16.60 -,137 1.705 -.296 ,2632 16.01 -.148 1.683 -,317 .2707 15,41 -,159 1,664 -.336 ,2786 14.93 -,168 1.651 -.350 .2850 14.45 -.175 1.640 -.360 .2910 14.02 -.180 1.635 -.366 ,2961 13.61 -.183 1,632 -,368 ,3000 13,22 -.184 1,632 -,368 .3041 12,88 -,184 1.632 -,368 .3075 12,54 -,184 1.629 -.371 .3113 12.21 -,186 1.627 -,374 .3152 11.91 -.187 1.621 -.379 ,3187 11.60 -.190 1.613 -.387 .3228 11.30 -.194 1.602 -,398 .3276 11,03 -,199 1.589 -.411 ,3320 10.74 -.206 1,573 -.428 ,3380 10.49 -,214 1.559 -.441 ,3427 10.22 -.220 1.549 -,452 ,3477 10,00 -.226 1.538 -.463 .3519 9.77 -.231 0.000 .047 .064 .080 .094 .107 .121 .133 .143 .154 .163 .171 .179 .187 .194 .200 .205 .211 .215 .220 .224 ,228 .232 .235 .239 .242 ,245 .248 .251 .254 .256 .258 .260 .262 .264 .266 .267 .269 .271 0.000 49.246 30.085 23.920 20.554 18.376 16.831 15.442 14.319 13,388 12.570 11.834 11.231 10.692 10.191 9.746 9.329 8.957 8.607 8.300 8.001 7,703 7.464 ~4 7.007 6,806 6,607 6.440 6,268 6.105 5.956 5.800 5.652 5.512 5,368 5,244 5.112 5.001 4.883 TABLE E.2 (cont'd) Tes Tes Elapsed Shear Shear Vert. Time Strain Stress Stress (min) (~) (ksf) (ksf) 83, 5,86 ,549 ,527 85, 6,05 ,555 ,524 87, 6,21 ,557 ,~o~ 89. 6.37 .562 .522 92, 6,57 ,567 ,519 94, 6,76 .571 ,514 96, 6.92 ,575 .506 98, 7,07 .578 ,497 100, 7,23 ,581 .487 102, 7,39 ,583 ,473 104, 7.55 .585 .462 106. 7,71 ,587 .449 108. 7.87 ,590 ,441 110, 8,02 ,593 .433 113, 8,23 ,597 ,430 114, 8,38 ,601 ,430 116, 8,54 ,604 ,433 118, 8,69 ,608 ,436 121, 8,86 ,611 ,436 122, 9,01 ,613 ,436 124. 9,17 .616 .433 127. 9.33 .619 .428 129. 9,49 .620 .419 130. 9.65 .621 .409 132. 9,81 .623 .398 135, 9.97 .624 .387 136. 10.13 .625 .382 138. 10,29 .627 ,376 140. 10.45 .628 .374 143, 10.61 ,630 ,374 144. 10.77 .631 .374 146. 10.93 .632 .376 148. 11.10 .634 .376 151, 11,26 ,635 .374 152. 11.42 .636 ,371 154, 11,58 .638 ,366 157. 11.75 .638 ,363 159, 11,91 ,639 .360 160. 1~.07 ,639 .358 162. 12.23 ,640 ,358 165. 12.39 ,642 .360 166. 12.55 .643 .360 168, 12.72 .645 .363 170. 12,88 .646 .363 173. 13.04 .646 .360 174. 13.20 .646 .355 176. 13.36 .647 .350 178. 13.52 .647 .341 181. 13.69 .647 ,333 182. 13.85 .647 ,32B 184. 14.01 .647 .323 187. 14.17 ,649 ,317 189. 14.34 .649 .315 190. 14.49 .650 .312 193. 14,68 .650 .309 196. 14.94 .651 .307 198. 15.10 .653 .304 t Hole...... t Number .... Delta 6v (ksf) -.468 I -.473 1 -.476 I -.479 1 -.479 1 -.481 I -,487 1 -.495 1 -.503 I -.514 I -.527 1 -,538 1 -.551 1 -.559 I -,567 i -.570 i -.570 1 -.567 1 -,565 1 -.565 i -.565 i -,567 I -.573 1 -.581 i -.592 i -.602 1 -.613 1 -,618 1 -,624 1 -.627 I -.627 I -,627 1 -,624 1 -.624 1 -.627 1 -,629 1 -.635 1 -.637 1 -.640 1 -.643 1 -.643 1 -.640 1 -.640 I -.637 1 -.637 1 -.640 1 -,645 1 -,651 i -.659 I -.667 I -.672 1 -.678 i -.683 1 -,686 1 -.688 1 -.691 1 -.694 1 -,696 AHC-B-2-87 3.0 - 4.5 ft. SS-1 Th/6v Modulus Delta6v Th/E (ksf) 6vc .3558 9.57 -.234 .3597 9,38 -.237 .3639 9.17 -.238 ,3664 8,98 -.239 .3690 8.82 -.239 .3733 8.64 -.241 .3773 8.45 -,243 .3820 8.32 -.247 ,3859 8.17 -.251 .3905 8.03 -.257 .3959 7.90 -.263 ,3998 7.75 -,269 .4054 7.62 -.276 .4095 7.50 -,280 .4137 7.39 -.284 ,4174 7.26 -.285 .4202 7.17 -.285 .4213 7.07 -.284 .4234 6.99 -.282 ,4253 6.89 -.282 ,4272 6.81 -.282 ,4299 6.72 -,284 .4334 6.63 -,286 .4368 6,53 -,290 .4411 6.44 -.296 .4455 6.35 -.301 .4499 6.26 -.307 ,4526 6.18 -.309 ,4554 6,09 -.312 .4573 6.01 -.313 .4583 5.93 -.313 .4593 5.86 -.313 .4594 5.78 -,312 ,4603 5.71 -,312 ,4622 5,64 -,313 .4641 5.57 -,315 .4670 5.51 -,317 .4679 5.43 -,319 .4698 5,37 -.320 .4707 5.29 -.321 ,4717 5,24 -,321 ,4718 5.18 -,320 .4728 5.12 -.320 .4729 5.07 -,319 .4739 5.02 -.319 ,4748 4,95 -,320 .4767 4.89 -.323 .4796 4.84 -.325 .4825 4.79 -.329 .4854 4.73 -,333 .4874 4.67 -,336 .4893 4.62 -.339 ,4924 4.58 -.341 .4934 4.52 -,343 ,4954 4,48 -.344 .4964 4.43 -.345 .4985 4.36 -.347 .5006 4,32 -,348 Th 6vt .273 .275 .277 .279 .281 .283 .285 .288 .289 .290 .292 .292 ,294 .295 .296 .298 .300 .302 .304 .305 .307 .308 .309 .310 .311 .311 .312 .313 .313 .314 .315 .315 .316 .317 ,317 ,318 .319 ,319 .319 .319 ,320 .321 .322 .323 .323 .323 .324 .324 .324 .324 .324 .324 ,324 .325 .325 .326 .326 Modulus 6vc 4.784 4.687 4.583 4.489 4,409 4.317 4.226 4.158 4.085 4.014 3.947 3.872 3.810 3.750 3.694 3.628 3.585 3.536 3.495 3.446 3,402 3,358 3.315 3.266 3,220 3.174 3,130 3.087 3.046 3.006 2.966 2.928 2.891 2.855 2.819 2.785 2.752 2.714 2.683 2.647 2.618 2.589 2,561 2.534 2.507 2.476 2.446 2.421 2.393 2.364 2.337 2,310 2.2B8 2.262 2.242 2,213 2.179 2.160 TABLE E.2 (cont'd) Test Mole ............. AHC-B-2-87 DePth ................. 3.0 - 4.5 ft. Test Number ..... , ..... SS-1 Elapsed Shear Shear Vert. Time Strain Stress Stress <min) (Z) (ksf) (ksf) 200, 15.26 ,653 1,298 202. 15.42 ,654 1.296 204, 15,58 ,654 1.290 206. 15.74 .655 1.288 208. 15.89 .655 1.285 210. 16.05 .657 1.285 212. 16.20 .658 1.285 21-4, 16.36 .659 1.288 216. 16.52 .661 1.288 218, 16,68 ,664 1,290 220. 16.84 .665 1.290 222, 17,00 ,666 1.290 224, 17.16 .668 1,290 226. 17,33 ,669 1.290 228, 17.49 ,670 1,288 261, 20.21 .687 1,255 263, 20,37 .687 1.253 265. 20.54 .687 1,253 267, 20.70 .687 1.250 269. 20.87 .687 1.247 288. 22.45 .685 1.226 502. 23.61 .680 1.207 306. 23.94 .680 1.202 310, 24,31 ,678 1,196 313, 24.52 .678 1.194 315. 24.69 .678 1,191 317. 24.85 .678 1,188 319. 25,02 .678 1.185 321. 25.18 .680 1.183 323. 25,35 .681 1.180 325. 25.51 ,683 1.180 327. 25.68 ,684 1.180 329. 25.84 ,685 1.180 531, 26.02 .687 1,180 333. 26.18 .687 1.180 335. 26.34 .687 1.177 337. 26.51 .687 1.175 339. 26.68 .685 1.169 341. 26,85 .684 1.164 343.' 27.02 ,681 1.159 345. 27,19 .680 1.151 Deltm Th/6v Modulus Delta6v 6v Th/E (ksf) (ksf) 6vc -.702 ,5026 4.28 -.351 -.705 .5047 4.24 -.352 -.710 .5068 4.20 -.355 -.713 .5090 4.16 -.356 -.715 .5100 4.12 -.358 -,715 .5111 4.09 -.358 -,715 .5121 4.06 -.358 -,713 .5121 4.03 -.356 -.713 .5132 4.00 -.356 -.710 .5142 3.98 -.355 -.710 .5153 3.95 -.355 -.710 .5163 3.92 -.355 -,710 .5174 3.89 -.355 -.710 .5184 3.86 -.355 -.713 .5206 3.83 -.356 -.745 .5470 3,40 -.372 -'.748 ,5481 3.37 -.374 -.748 .5481 3.34 -.374 -.750 .5493 3.32 -.375 -.753 .5505 3.29 -.376 -.774 .5590 3.05 -.387 -.793 .5633 2.88 -.397 -.799 .5658 2.84 -.399 -.804 .5672 2.79 -.402 -.807 ,5685 2.77 -.403 -.809 .5697 2,75 -.405 -,812 .5710 2,73 -.406 -.815 ,5723 2.71 -.407 -.817 .5748 2.70 -.409 -.820 .5772 2,69 -.410 -.820 .5784 2,68 -.410 -.820 ,5795 2.66 -.410 -,820 .5807 2.65 -.410 -.820 .5819 2.64 -.410 -.820 .5819 2.62 -.410 -.823 .5832 2.61 -,411 -.826 .5845 2,59 -.413 -.831 ,5860 2.57 -.415 -,836 .5876 2,55 -.418 -.842 ,5880 2,52 -.421 -,850 .5909 2.50 -.425 Th 6vc .326 ,327 .327 .328 .328 .328 .329 .330 .330 .332 .332 .333 .334 .334 .335 .343 ,343 .343 .343 .343 .343 .340 .340 ,337 .339 .339 .339 .339 ,340 .341 .341 .342 .343 .343 ,343 .343 .343 .343 ,342 .341 .340 Modulus 6¥c 2.138 2.120 2.099 2.082 2.062 2.046 2.031 2.016 2.000 1.989 1.974 1.960 1.945 1.930 1.916 1.699 1,685 1.671 1,658 1.645 1.526 1,440 1.420 1.395 1.383 1.374 1.365 1.356 1,350 1.343 1.338 1.332 1.326 1.319 1.311 1.303 1.295 1.284 1.273 1.260 1.250 Test no. SS-1 0" (ks'F) 2. O0 Init. Dry dens. (lb/cu.~t.) 68.2 0 r' 0 L. 0 1. O0 · 75 · 5O · 25 O. O0 1. O0 · 50 0 O0 _i 50 -1. O0 ! I 10 15 Shear Strain (%) 5 10 15 Shear Strain (%) 20 25 2O 25 AMERADA HESS SIMPLE SHEAR TEST F I GURE E. 20 Test no. c7~' c (ks?) Dry SS-1 2. O0 68.2 Init. dens. (1 b/cu. rt. ) 0 .8 .6 .4 .2 .0 2.0 I & I I 5 10 15 20 Shear Strain (%) 1.5 1.0 .5 & I I O .5 1. O 1.5 2.0 2.5 Vertical Stress (ks?) AMERADA HESS SIMPLE SHEAR TEST F I GURE E.2b TABLE E.3 SIMPLE SHEAR TEST DATA Date Tested,.,, ....... 87-06-08 Job Number .... ,..,..,, 0501-4667 Test Hole.., .... ,.,,.. AHC-B-2-87 DePth, ....... ,,,,.,,., 3.0 - 4.5 ft. Test Number....,,.,,.. SS-2 Strain rate (% Per min) .072 Normal Stress,.(ksf).. 4.01 INITIAL FINAL Water Content (%) 53. 40. Wet Densit~ (Pcf) 103,3 N/A Dr~ Densit~ (Per) 67.7 N/A E Th 6v ElaPsed Shear Shear Vert, Delta Time Strain Stress Stress 6v (min) (%) (ksf) (ksf) (ksf) Th/6v Modulus Delta6v Th/E (ksf) 6vt Th 6vt Modulus 6ye O. 0.00 0,000 4.009 0.000 2. .17 .099 3.996 -.013 3, .29 ,159 3.979 -,030 5. .42 .224 3.963 -.046 8, .65 ,324 3.931 -.078 10. .77 .375 3.915 -.094 12. .97 .454 3.880 -.129 14. 1.11 .504 3.856 -.153 17. 1.29 .563 3,821 -.188 18. 1.38 .591 3.802 -.207 19. 1.49 .621 3.780 -.229 21. 1.62 .657 3.748 -.261 24, 1.82 .703 3.700 -.309 26. 1.96 .732 3,662 -.347 28. 2.10 .759 3,622 -.387 30. 2.25 .783 3.581 -.428 32. 2.39 ,805 3.544 -.465 34. 2.54 .825 3.503 -.506 37. 2.76 .854 3,450 -.559 39. 2.91 .870 3.415 -.594 41. 3.05 .887 5.382 -.627 43. 3,20 .900 3.356 -.653 45, 3.35 .915 3.329 -.680 47. 3.50 .927 3.307 -.702 49. 3.65 .940 3.286 -.723 51. 3.80 .952 3.26.4 -.745 53. 3.96 .963 3,245 -.764 55. 4.11 .972 3.226 -.783 57. 4.25 .982 3.205 -.804 59. 4.41 .991 3.183 -.826 61. 4.55 1.001 3.162 -.847 63. 4.70 1.009 3,143 -.866 65. 4.85 1.017 3.122 -.887 67. 5.00 1.025 3.103 -.906 69. 5.14 1.032 3,084 -.925 71. 5.29 1.040 3.068 -.941 73. 5.44 1.047 3,049 -.960 75. 5.59 1.054 3.033 -.976 77. 5.74 1.061 3.019 -.990 0.0000 0.00 0.000 0.000 0.000 · 0248 59.94 -.003 .025 14.950 .0400 55.60 -.007 .040 13.869 .0566 52.98 -.011 .056 13.215 ,0823 50.06 -.019 .081 12.488 .0959 48.88 -.023 .094 12.192 .1171 46.82 -.032 .113 11.678 .1308 45.35 -.038 .126 11.311 .1473 43.68 -.047 .140 10.897 .1556 42.83 -.052 .148 10.684 .1644 41.83 -.057 .155 10.435 .1752 40.44 -.065 .164 10.087 .1900 38.64 -.077 .175 9.639 .1998 37.28 -.087 .182 9.300 °2095 36.05 -.097 .189 8.993 .2187 34.81 -.107 .195 8.683 .2271 33.62 -.116 .201 8.387 .2356 32.51 -.126 .206 8.110 .2475 30.95 -.140 .213 7.719 .2548 29.95 -.148 .217 7.471 .2621 29.03 -.156 .~1.~ 7.242 .2683 28.11 -.163 .225 7.013 .2749 27.30 -.170 .228 6.809 · 2804 26.48 -.175 .231 6.605 .2860 25.73 -.180 .234 6.417 .2916 25.02 -.186 .237 6.242 .2966 24.34 -.191 .240 6.071 .3013 23.68 -.195 ,243 5.907 .3063 23.07 -.201 ,245 5.755 .3114 22,50 -.206 .247 5.612 .3165 21.97 -.211 .250 5.481 .3210 21,46 -.216 .252 5,353 .3258 20.98 -.221 .254 5.233 .3304 20.52 -,226 .256 5.118 · 3346 20.06 -.231' .257 5.005 .3391 19.66 -.235 .259 4.903 .3434 19.25 -.239 .261 4.801 .3475 18.84 -.243 .263 4.701 .3513 18.47 -.247 .265 4.607 TABLE E.3 (cont'd) Test Hole Depth Test Number ElmPsed Shear Shear Time Strain Stress (min) (%) (ksf) Vert, Delta Stress 6v <ksf) <ksf) AHC-B-2-87 3,0 - 4.5 ft. SS-2 Th/6v Modulus Delta6v Th Th/E .... (ksf) 6v¢ 6ye Modulus 79, 5,89 1,067 81, 6,05 1,074 83, 6,21 1,080 85. 6.36 1,086 87, 6,52 1,092 89. 6,68 1,097 91, 6,84 1,103 93, 6,99 1,107 95. 7.15 1.112 97. 7,31 1,116 99. 7.47 1,119 101. 7.62 1,123 103. 7,78 1,126 105. 7,94 1,129 107. 8,10 1,131 109. 8,25 1,134 111, 8,41 1,135 113, 8,57 1,138 115. 8,73 1,141 117, 8.89 1,142 119, 9.05 1,145 121, 9.21 1,148 123, 9,37 1.149 125. 9,53 1.152 127, 9,69 1,153 129, 9,85 1,154 131, 10,01 1,156 133, 10,17 1.157 135, 10,33 1.158 137, 10.49 1,160 139, 10,65 1,160 14.1, 10,81 1,161 143. I0,98 1.161 145. 11,14 1,161 147, 11,30 1,161 149. 11,46 1,163 151, 11,63 1,163 153. 11,79 1,163 155, 11,95 1,163 157. 12,12 1,164 159. 12,32 1,165 162, 12,52 1.167 165. 12.73 1.169 166, 12,89 1,171 168, 13,05 1.173 170, 13,21 1.175 173, 13,37 1,178 174, 13,53 1,179 176, 13,69 1.182 178, 13,85 1,183 181, 14,02 1.186 182, 14,18 1,187 187. 14.55 1,191 189, 14,71 1.194 191, 14,87 1,195 193, 15,08 1.198 196, 15.24 1.199 197, 15,40 1,201 3,003 -1,006 2,987 -1,022 2,971 -1,038 2,958 -1.051 2.944 -1,065 2,928 -1,081 2.914 -1,094 2,901 -1,108 2,888 -1.121 2.874 -1.135 2.858 -1,151 2.845 -1,164 2,828 -1,181 2,812 -1,197 2,796 -1,213 2,780 -1,229 2,767 -1,242 2,753 -1,256 2,740 -1,269 2,729 -1,.280 2,718 -1,291 2,707 -1,302 2,697 -1,312 2,683 -1.326 2,672 -1,336 2.662 -1,347 2,648 -1,361 2,638 -1,371 2,627 -1,382 2,616 -1,393 2,608 -1,401 2,600 -1,409 2,592 -1,417 2,584 -1,425 2,576 -1,433 2,568 -1,441 2,560 -1,449 2,554 -1,455 2,546 -1,463 2,541 -1,468 2,533 -1,476 2,5°~ -1,487 2.514 -1,495 2,506 -1,503 2,498 -1,511 2,490 -1,519 2.482 -1,527 2,476 -1.533 2,468 -1.541 2,460 -1.549 2.452 -1.557 2.444 -1.565 2,428 -1.581 2,422 -1.587 2,414 -1.595 '2.406 -1,603 2.401 -1,608 2,395 -1,613 .3554 .3596 ,3634 ,3673 ,3709 ,3748 .3784 .3815 ,3852 ,3884 .3915 ,3948 ,3980 ,4013 .4046 ,4079 ,4104 .4134 ,4164 .4185 ,4212 ,4237 ,4261 .4292 ,4314 ,4337 ,4364 .4387 ,4410 ,4434 ,4447 ,4466 ,4480 ,4494 ,4508 .4528 .4542 .4552 ,4566 ,4581 ,4601 ,4626 .4652 .4672 .4698 ,4719 ,4745 ,4761 .4787 .4809 ,4836 ,4857 ,4906 ,4928 .4950 .4978 .4995 ,5012 18,11 -,251 ,266 17,76 -,255 ,268 17,40 -,259 ,269 17,08 -,262 .271 16,75 -,266 ,272 16,43 -.270 ,274 16.13 -.273 ,275 15,83 -,276 .276 15,55 -.280 ,277 15,27 -,283 ,278 14,99 -.287 ,279 14,73 -.290 ,280 14,47 -,294 ,281 14,21 -,298 ,282 13,97 -.303 .282 13,74 -.307 ,283 13,50 -.310 ,283- 13,28 -,313 ,284 13,07 -,317 .285 12.85 -,319 ,285 12,65 -.322 ,286 12,46 -,325 ,286 12,27 -,327 ,287 12,09 -,331 .287 11,90 -,333 .288 11,72 -,336 ,288 11,55 -,339 ,288 11,38 -,342 .289 11,22 -,345 ,289 11,06 -,347 .289 10.89 -,349 .289 10.74 -,351 ,290 10.58 -.354 .290 10,43 -,356 .290 10,28 -.358 .290 10,14 -,360 ,290 10,00 -,362 .290 9,86 -.363 .290 9.73 -.365 .290 9,61 -,366 .290 9,46 -,368 .291 9,31 -,371 .291 9.19 -,373 .292 9.08 375 8.99 -.377 .293 8,89 -,379 .293 8,81 -.381 .294 8,71 -,382 ,294 8,63 -,384 .295 8.54 -,386 ,295 8,46 -,388 .296 8,37 -,390 ,296 8,19 -,394 ,297 8,12 -,396 .298 8,04 -,398 .298 7.95 -,400 .299 7,87 -,401 .299 7.79- -.402 .299 4.517 4.429 4,339 4,259 4,178 4.099 4,024 3,948 3,880 3.809 3,738 3.674 3.609 3,546 3,485 3,.427 3,367 3,312 3,260 3,206 3.157 3,109 3,060 3.016 2.969 2.924 2,881 2.839 2.798 2.758 2,716 2,679 2.639 2,601 2.564 2,530 2.494 2.460 2.426 2.396 2,359 2.323 2.o9o 2.266 2.243 2,218 2.197 2.173 2,152 2,130 2,110 2.088 2.043 2.025 2.005 1.982 1,963 1.944 Tes DeP Tes TABLE E.3 (cont'd) ElaPsed Shear Shear Time Strmin Stress (min) (%) (ksf) 199. 15,56 1,203 201, 15,72 1,205 204. 15,89 1.206 206. 16.05 1,209 208, 16.20 1,210 210. 16,40 1,213 212, 16.56 1.216 214, 16.75 1,217 216. 16.91 1,220 219. 17.07 1,221 221, 17,27 1,224 223. 17.42 1.225 225, 17,59 1.~8 227, 17,75 1.229 229. 17.91 1.231 231, 18,07 1.233 233, 18,24 1,235 235. 18,44 1.237 237. 18.60 1,239 240. 18,77 1,240 241, 18.93 1,241 243, 19,09 1,243 245, 19,25 1,244 248. 19.42 1,245 249, 19.58 1,247 251. 19,74 1.247 253. 19.91 1,248 256, 20,07 1,248 257. 20.23 1,248 259, 20.40 1.250 261, 20.56 1,250 264. 20.73 1.250 265. 20,89 1.25I 267, 21.06 1.251 270. 21,23 1,25I 271, 21,39 1,252 274, 21 64 1 ~ ~ 276. 21,81 1,252 279. 22,02 1,254 281, 22,22 1,254 285, 22,52 1.254 287, 22,68 1,255 289, 22,83 1,255 291, 23,00 1,255 293, 23,16 1,255 295, 23,33 1,255 297. 23,49 1,256 299, 23,66 1..255 301, 23,82 1,255 303. 23,99 1,255 306. 24.24 1,255 308. 24,41 1.255 310, 24,57 1,255 312, 24.73 1.255 314. 24.91 1.256 316. 25.07 1.258 318. 25.23 1.259 320, 25.40 1.260 t Hole ............. AHC-B-2-87 th ................. 3.0 - 4.5 ft. t Number ........... SS-2 Vert. Delta Th/6v Modulus Delta6v Stress 6v Th/E (Esl) (Ksf) (Ksf) 6vc 2,390 -1,619 ,5035 7,73 -,404 2,385 -1,624 ,5052 7.66 -,405 2,379 -1,630 ,5069 7,59 -,406 2.374 -1,635 .5092 7,53 -,408 2,371 -1,638 ,5103 7,47 -,409 2.366 -1,643 ,5126 7,40 -.410 2,363 -1,6.46 ,5144 7,34 -,411 2,358 -1.651 .5161 7,26 -,412 2,355 -1,654 ,5179 7.21 -,413 2,352 -1,656 ,5190 7.15 -,413 2,350 -1.659 ,5208 7.09 -.414 2,347 -1,662 ,5220 7.03 -,415 2,344 -1,665 ,5237 6.98 -.415 2,342 -1,667 ,5249 6,92 -,416 2,339 -1,670 ,5261 6,87 -.417 2,339 -1,670 ,5273 6.82 -.417 2.336 -1,673 .5284 6.77 -.417 2,336 -1,673 ,5296 6,71 -,417 2,334 -1,675 ,5308 6,66 -,418 2,331 -1.678 ,5320 6.61 -,419 2,328 -1,681 ,5332 6.56 -,419 2,323 -1.686 .5350 6.51 -,421 2.315 -1,694 .5375 6,46 -,423 2,307 -1,702 ,5399 6,41 -,425 2,299 -1,710 ,5424 6,37 -,427 2,291 -1,718 ,5443 6,32 -,429 2,283 -1,726 ,5469 6,27 -,431 2,277 -1,732 ,5481 6,22 -,432 2.269 -1,740 ,5501 6,17 -,434 2.266 -1,743 ,5513 6,13 -,435 2,261 -1,748 ,5527 6.08 -,436 2,258 -1,751 ,5533 6,03 -,437 2,256 -1,753 ,5546 5.99 -,437 2.250 -1.759 .5559 5.94 -.439 2.248 -1.761 .5566 5,89 -.439 2.245 -1.764 .5578 5.85 -,440 2,242 -1,767 .5585 5.79 -,441 2,240 -1,769 ,5592 5.74 -.441 2,237 -1,772 .5605 5,69 -,442 2,234 -1,775 ,5611 5,64 -,443 2,234 -1,775 ,5611 5,57 -,443 2,234 -1,775 ,5617 5.53 -.443 2,237 -1.772 ,5611 5,50 -,442 2.237 -1.772 .5611 5.46 -.442 2,237 -1,772 ,5611 5,42 -,442 2,237 -1.772 ,5611 5,38 -.442 2,234 -1,775 ,5624 5.35 -,443 2,229 -1,780 ,5631 5,30 -,444 2,223 -1,786 ,5645 5,27 -,445 2,215 -1,794 ,5665 5.23 -,447 2,205 -1,804 ,5693 5,18 -,450 2,196 -1,812 .5714 5.14 -,452 2.188 -1,821 ,5735 5,11 -,454 2.183 -1.826 ,5749 5.07 -.455 2,178 -1,831 .5769 5,04. -,457 2,178 -1,831 ,5776 5.02 -,457 2,180 -1,829 ,5775 4,99 -,456 2,183 -1,826 .5774 4,96 -,455 Th 6vc .300 ,301 .301 .302 ,302 ,303 .303 ,304 .304 ,305 ,305 ,306 ,306 ,307 ,308 ,308 .309 .309 .309 .310 ,310 ,310 ,311 .311 ,311 ,311 ,311 ,311 ,312 ,312 ,312 ,312 ,312 ,312 ,312 .312 ,312 ,313 .313 ,313 ,313 .313 ,313 ,313 ,313 ,313 ,313 ,313 ,313 .313 .313 ,313 ,313 ,313 ,314 ,314 ,314 Modulus 6v¢ 1,929 1.911 1,894 1.879 1,863 1.B45 1,831 1,812 1.799 1,784 1,768 1.754 1,741 1,727 1,714 1,702 1,688 1,674 1.661 1,648 1,636 1,624 1.612 1,600 1.588 1,575 1.564 1.551 1,539 1.528 1,516 1,504 1,493 1,482 1,470 1,460 1,443 1,433 1.420 1,407 1.389 1,381 1,371 1,361 1,351 1,342 1.334 1.323 1,314 1,305 1,292 1,283 1,274 1.266 1. 258 I, 252 1,245 1,238 Test no. c7' (ks?) SS-2 4.01 Init. Dry dens. (lb/cu. ?t. ) 67. ? 0 o 2. O0 1.50 1. O0 · 50 O. O0 5. O0 2.50 O. O0 -2.50 -5. O0 5 10 15 Shear Strain (Z) I. I I i I 5 lO 15 Shear Strain 20 25 AMERADA HESS SIMPLE SHEAR TEST FIGURE F_3a Test no. cF~' .(ksF) Dry SS-2 4. O1 57.7 Init. dens. (lb/cu. Ft. ) 0 .8O · 6O · 4O · 2O · O0 4. O0 & I ! I 5 10 15 Sheor Stroin ,m 0 J~ 3. OD ?. O0 1. OD 2.0 3.0 4.0 Verticol Stress i AMERADA HESS SIMPLE SHEAR TEST F I GURE E. 3b APPENDIX F CONSOLIDATION TEST RESULTS APPENDIX F CONSOLIDATION TEST RESULTS A one-dimensional consolidation test was conducted on one soil sample in order to evaluate the stress history, compressibility and permeability of the soil. The consolidation test results are presented on Table F.1 and Figure F.1. The consolidation test was conducted on a sample 2.4 inches in diameter by 1.0 inches in height. The test procedure is outlined below: The sample was set up in oedometer with dry stones. Standard incremental loading was applied to a specified vertical effective stress that exceeds the in situ effective overburden pressure. The oedometer was then flooded with a saline solution of similar salinity to that of the soil, the specimen loaded in increments of 50% increase until a specified~ vertical effective stress was reached. An unload-reload loop was incorporated, in the vicinity of the estimated preconsolidation pressure. Thereafter, the standard doubling of pressures was resumed to test completion. All load increments were left on for a time interval determined by the root time method. This procedure incorporates modifications made to standard procedure (ASTM D2453) according to Andresen et al., (1979) and Broms (1980), as recommended for overconsolidated soils. The procedure is considered appropriate in view of the large reduction in total stress that typically occurs upon sampling. TABLE F.1 CONSOLIDATION TEST DATA ---- Load (ksf) 0.000 .021 .073 .125 ,438 ,752 1,587 .209 .647 1,587 3.132 6.264 12.528 25.056 50.112 2.088 .073 Date Computed.. ....... 10t48 AM Date Tested...,.,.....87-06-11 Job Number............0501-4667 THU., JULY, Test Hole.. ........ ...AHC-B-2-87 DePth.. ...... . ........ 3.0 - 4.5 ft. Test Number ..... ROOT Fit INITIAL FINAL Height (in) 1.01 Water Content (%) 26.57 Wet Densit~ (Pcf) 117,25 Dr~ Densit~ (Per) 92,64 Void Ratio ,7088 Saturation (%) 100.00 .85 15.71 127.53 110.22 .4209 100.00 (Assumed) Void ratio CV(sa,ft/~r) MV(sa.ft/kiP) .708B .O00E+O0 ,O00E+O0 .6954 .543E+03 .378E+00 .6793 ,225E+03 ,184E+00 .6614 .356E+02 .206E+00 .6429 .486E+02 ,108E+00 .6229 .706E+02 ,589E-01 .5961 .574E+02 .537E-01 .5605 .169E+03 .273E-01 .5727 .O00E+O0 ,O00E+O0 .5679 .279E+03 .697E-02 .5551 .425E+03 .872E-02 .5194 ,~3E+03~ .152E-01 .4721 ,312E+03 .103E-01 ,4195 .368E+03 ,591E-02 .3651 ,343E+03 .318E-02 .3069 .253E+03 .178E-02 .3421 ,O00E+O0 .O00E+O0 .4209 .O00E+O0 ,O00E+O0 K(ft/s) .O00E+O0 ,406E-06 .820E-07 .145E-07 ,104E-07 .823E-08 .610E-08 ,915E-08 .O00E+O0 .385E-08 ,734E-OB .672E-08 .635E-08 ,430E-08 .216E-08 .890E-09 ,O00E+O0 .O00E+O0 1987 CONSOLIDATION TEST RESULTS Project: Amerada Hess Corporation Address::._Site B, Northstar/Seal Area 0501-4667 Project No.' Date Tested' 87-06-11 By: -- · 800 · 700 · 600 .500 · 400 · 900 Test No.: C- 1 Borehole No.: AHC-B-2-87 Depth (feet): Diameter (in.): 2. 492 Specific Gravity: 2. 680 .O1 .1 1 10 102 Pressure (ksf) Height (in.): Water Content (%): Wet Density (pcf): Dry Density (pcf) Void Ratio Saturation (%): INITIAL FINAL Sample Description: 1,009 .848 dork 9rex, mottlod_. 26. 57 15. 71 Overburden Pressure 17. 25 ~ Swelling Pressure g2. 64 ~ Pre-Consolidation Pressure · 7088 ,4209 Compression Index 00. O0 1 ilO_ O0 SILT. trc. ~ine sond P~ p~ I .5 Cc O. 20 ksf ksf ksf Tested in accordance with ASTM stan~lard 02435 unless otherwise noted. 2130/3779 8)' ' ' (]4 r. aru 2.2) (6) Add: 1 Is the permit fee a~-~ached 3' YES NE) ~ - 2. Is w~ll to be located in a defined pool ... .......................... .3. Is w~ll located prop~ disrznce from proD~ line .................. 4 Is ~ located p ~roper distance frc~ or.h~ wells S. Is sufficien~ undedica~e~ acreage available in this pool ............ 6. Is ~ no be daviate~ an~ is wellbore plat incl~ ................ 7 Is operator the only affected par~ 8. Can pez~i~ be approved before fifteen-day wai~ ...................... 9. Does operator have a bond in force .................................. 10. Is a conservation ord?v needed ...................................... 11 Is ad~.~tra~ive approval-needed 1Z. Is the lease r.~her appropriate .......................... 14. Is conduc=or string pmmvidad ........................................ J,, ,,, 15. Will surface casirg protect fresh water zones ....................... 16. Is enough cemsmt used ~o ci=~te on conduc=or amd surface ......... 17. Will cemsmt tie in surface and imtermedq~te or produc=ion strings ... 18. Will ¢~at cover all known pz~d~c=ive heriz: ..................... 19. Will all casing give adequate safe~y in collapse, tension and burst.. 20. Is this well to be kicked off frc~ an existing w~11bore ............ 21. Is old w~Llbore aban~t proce~e imctude~ on 10-403 ............ 22. Is adequate we!lbore separation proposed ............................ _ ,,,, ,, 23. Is a div~r~er system re~red ................... 24. Is the d~ fluid prog=mn scb~tic and list g~ ..... ° ............. equi?~t adequate 25. Are necessary diagrm-~ amd descriptions of diver~er and BOPE attached. 26. Does BOPE have sufficient pressure rating - Test to ~oo ~ psig .. 27. Does :ha choke ~*ola comp.~y w/API RP-53 ~ay 84) .................. 28. Is ~ha p=es~ of ~S~ gas probable ................................. For exploratory and St~atigraphic w~Lls: 29. Az~ data presented on potential ov~rpressure zones? ................ 30. Are seismic ~n~lysis da~a presented on shallow gas z~es .... , .......ed~ 31. If am offshore loc., are suzvay =esults of seabed condi~ns present 32 Additicm~l recp~ments - ,.~ ,, Geolo~: rev: 01/28/87 6.011 POOL CLASS STATUS AREA NO. SHORE ,, , , ,,