One indicator that MMS has found useful in projecting activity levels is the number <strong>of</strong> plans received. Although the order <strong>of</strong> plan submission and drilling activities can vary with projects, operators generally proceed as follows: • file an Exploration Plan (EP), • drill exploratory wells, • file a Conceptual Deep Water Operations Plan (DWOP), • file a Development Operations Coordination Document (DOCD), • file a Preliminary DWOP, • drill development wells, then • begin production. Figure 38 shows the number <strong>of</strong> deepwater EP’s, deepwater DOCD’s, and DWOP’s received each year since 1992 (DWOP’s were not required until 1995). The count <strong>of</strong> EP’s and DOCD’s includes initial, supplemental, and revised plans; only the initial submittals (Conceptual Part) <strong>of</strong> the DWOP’s are shown. Some shallow-water activities are included in the DWOP data because DWOP’s must be filed and approved for developments in greater than 1,000-ft (305 m) water depths and for all subsea developments regardless <strong>of</strong> water depth. The discussion <strong>of</strong> subsea wells later in this report will address the significance <strong>of</strong> shallow-water subsea tiebacks—the effective use <strong>of</strong> deepwater technologies in shallow-water marginal developments. There was a marked increase in EP’s, DOCD’s, and DWOP’s beginning in 1996. In recent years, however, there has been a moderate decrease in these plans. Until recently there had been a gradual increase <strong>of</strong> drilling depth (as measured in true vertical depth [TVD]). Since 1996 the maximum drilling depth has increased rapidly, reaching depths below 30,000 ft (9,144 m) in 2002. Figure 39 shows the maximum TVD <strong>of</strong> wells drilled each year since 1965. The maximum TVD increased gradually from 17,500 ft (5,334 m) in 1965 to 26,978 ft (8,223 m) in 1998. The recent dramatic increase in TVD to a record 31,824 ft (9,700 m), reached in 2003, may be attributed to several factors, including enhanced rig capabilities, deeper exploration targets, and the general trend toward greater water depths. Figure 40 shows the maximum water depth drilled in the entire GOM each year since 1965. The progression into greater water depths has been very rapid. <strong>Deepwater</strong> drilling began in 1975; significant water depth records occurred in 1976 (1,986 ft or 605 m), 1983 (3,530 ft or 1,076 m), and 1987 (7,500 ft or 2,286 m). In November 2003, ChevronTexaco set a world record – drilling in 10,011 ft (3,051 m) <strong>of</strong> water at its Toledo prospect in Alaminos Canyon Block 951. DEVELOPMENT SYSTEMS Development strategies vary for deepwater depending on reserve size, proximity to infrastructure, operating considerations (such as well interventions), economic considerations, and an operator’s interest in establishing a production hub for the area. Figure 41 shows the different systems that can be used to develop deepwater discoveries. Table 4 lists the systems that have begun production. In contrast to the MMS field designations used in the 2002 report, table 4 now lists operator-designated project names. Fixed platforms (e.g., Bullwinkle) have economic water-depth limits <strong>of</strong> about 1,400 ft (427 m). Compliant towers (e.g., Petronius) may be considered for water depths <strong>of</strong> approximately 1,000-3,000 ft (305-914 m). Tension-leg platforms (TLP’s) (e.g., Brutus and Typhoon) are frequently used in 1,000- to 5,000-ft (305- to 1,524-m) water depths. Spars (e.g., Genesis), semisubmersible production units (e.g., Na Kika), and floating production, storage, and <strong>of</strong>floading (FPSO) systems (none in GOM) may be used in water depths ranging up to and beyond 10,000 ft (3,048 m). Figure 42 shows three <strong>of</strong> these development systems: a TLP, a spar, and a semisubmersible. 58
180 160 <strong>Deepwater</strong> EP <strong>Deepwater</strong> DOCD DWOP 152 158 144 142 135 140 59 Number <strong>of</strong> Plans Received 25 3 25 4 35 4 38 7 5 125 120 100 80 60 64 105 40 40 19 32 24 26 26 34 35 35 31 25 32 20 10 11 16 14 0 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 Year Figure 38. <strong>Deepwater</strong> EP's, DOCD's, and DWOP's received in the <strong>Gulf</strong> <strong>of</strong> <strong>Mexico</strong> since 1992.
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ON COVER - The cover features four
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Table of Contents Page PREFACE.....
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Figures Page Figure 1. The Gulf of
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Figures — continued Page Figure 5
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Tables Page Table 1 List of Deepwat
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INTRODUCTION The deepwater Gulf of
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BACKGROUND DEFINITIONS The GOM Oute
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EXPANDING FRONTIER When the origina
- Page 21 and 22: 1992 - 1993 Louisiana Mississippi A
- Page 23 and 24: 1992 - 2003 Texas Louisiana Mississ
- Page 25 and 26: fffffffffffffffff 1500 ft Quaternar
- Page 27 and 28: In addition to the traditional oil
- Page 29 and 30: 15 Figure 8. Gas hydrates on the se
- Page 31 and 32: 1998 - 1999 Louisiana Mississippi A
- Page 33 and 34: 4,500 4,000 Number of Active Leases
- Page 35 and 36: ENVIRONMENTAL ACTIVITY The extensiv
- Page 37 and 38: Operators submit a remotely operate
- Page 39 and 40: 25 Figure 15. Loop and eddy current
- Page 41 and 42: 1975 - 1979 Louisiana Mississippi A
- Page 43 and 44: 29 Deepwater Discoveries $ #Y Texas
- Page 45 and 46: 31 Texas ð PORT ARANSAS 1000 ft 15
- Page 47 and 48: Louisiana Mississippi Alabama 33 Te
- Page 49 and 50: Pipelines New pipelines Proposed pi
- Page 51 and 52: LEASING Until the mid-1990's, leasi
- Page 53 and 54: Number of Leases Bid On 600 500 400
- Page 55 and 56: 1998 - 1999 Louisiana Mississippi A
- Page 57 and 58: 1992 - 1993 Louisiana Mississippi A
- Page 59 and 60: 2004 - 2005 (741 leases) Louisiana
- Page 61 and 62: DRILLING AND DEVELOPMENT Deepwater
- Page 63 and 64: 49 Figure 30. The Discoverer Deep S
- Page 65 and 66: 51 Number of Wells Spudded 250 200
- Page 67 and 68: 120 > 7,500 ft 107 108 100 5,000 -
- Page 69 and 70: 1998 - 1999 Louisiana Mississippi A
- Page 71: 1998 - 1999 Louisiana Mississippi A
- Page 75 and 76: 340 626 390 472 472 456 393 475 590
- Page 77 and 78: Year of First Production Table 4 De
- Page 79 and 80: Year of First Production Table 4 De
- Page 81 and 82: A predominant workhorse of the GOM
- Page 83 and 84: 3 Number Installed 2 1 0 2004 69 TL
- Page 85 and 86: Flow lines to host platform Subsea
- Page 87 and 88: 140 131 120 100 78 Number of Wells
- Page 89 and 90: RESERVES AND PRODUCTION The deepwat
- Page 91 and 92: 77 Million Barrels of Oil Equivalen
- Page 93 and 94: 18 16 14 12 10 8 Number of Fields 6
- Page 95 and 96: 81 Million Barrels of Oil Equivalen
- Page 97 and 98: 45,000 40,000 Million Barrels Oil E
- Page 99 and 100: 1992-1993 1994-1995 1996-1997 Lease
- Page 101 and 102: S hallo w- wa ter GOM 11% Deepwater
- Page 103 and 104: 1,200,000 1,000,000 Total productio
- Page 105 and 106: 1,100,000 1,000,000 Subsea oil Tota
- Page 107 and 108: 900,000 800,000 Majors Nonmajors 70
- Page 109 and 110: 45,000 40,000 Max oil rate 1,000-1,
- Page 111 and 112: 4,000 3,500 Shallow water Deepwater
- Page 113 and 114: Texas Auger Louisiana SS182 Troika
- Page 115 and 116: SUMMARY AND CONCLUSIONS This report
- Page 117 and 118: 2,500 Number of leases Average U.S.
- Page 119 and 120: Number of Years 14 12 leas es in p
- Page 121 and 122: data for this analysis include only
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80 2500 70 60 Number of leases dril
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4,500 4,000 3,500 Leases tested Lea
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• Nonmajor companies have made mo
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REFERENCES Bascle, B. J., L. D. Nix
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Project Name Area/Block Water Depth
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Project Name Area/Block Water Depth
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Project Name Area/Block Water Depth
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Project Name Area/Block Water Depth
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Project Name Area/Block Water Depth
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Project Name Area/Block Water Depth
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Sale Number Sale Location Sale Date
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Completed Studies [MMS Study Number
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Group Name Company Name MMS Number
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Group Name Company Name MMS Number
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Appendix G. Subsea Completions. Are
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Area Block API Number Operator Comp
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Area Block API Number Operator 144
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Area Block API Number Operator Comp
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Area Block API Number Operator Comp
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Year Shallowwater Oil (MBOPD) Deepw