Timbalier Bay Research Articles

Geographic Variability in Salt Marsh Flooding Patterns may Affect Nursery Value for Fishery Species

Flooding of salt marshes controls access to the marsh surface for aquatic organisms and likely regulates the value and use of this habitat for juvenile fishery species. We examined geographic variability in marsh access by measuring tidal flooding characteristics in 15 Spartina alterniflora marshes in the southeastern US between South Texas and lower Chesapeake Bay. Flooding duration and flooding frequency were correlated with the elevation of the marsh edge in relation to mean low water and with the tidal range. Mean annual flooding duration over the years 2006–2008 was highest in Texas (91.5% in Aransas Bay) and North Carolina (89.3% in Pamlico Sound) and lowest in Timbalier Bay, LA (54%) and the lower Carolinas and Georgia (55–57%). We used published data on densities of blue crabs and penaeid shrimps as a measure of habitat selection, and there was a positive relationship between marsh selection and flooding duration.

A gradient of dissolved organic carbon and lignin from Terrebonne–Timbalier Bay estuary to the Louisiana shelf (USA)

Here we report on spatial and temporal changes in the concentration and composition of total dissolved organic carbon (DOC) and dissolved lignin-phenols (sum 8) in surface and bottom waters in estuarine and inner shelf off the Louisiana coast (USA). DOC samples were collected at 6 stations on 3 cruises (April 2008, July 2008) for organic analyses along a transect that spanned from inside Terrebonne–Timbalier Bay estuary, Louisiana (7 m water depth) to the outer-most station on the inner Louisiana shelf (18.5 m water depth). An additional set of samples was taken for DOC and dissolved lignin-phenols in April 2009 in the upper marshes of the estuary in water depths typically ca. 1 m. Hydrographic properties of shelf waters in April 2008 were drastically different than in July 2008 because of the higher river discharge from the Mississippi River (MR) and the opening of man-made water diversion structures in Louisiana in April. There were no significant differences in DOC concentrations between the inner bay and shelf stations, likely due to extensive mixing between the bay and shelf waters. However, there were significantly higher concentrations of dissolved lignin (sum 8) and Λ 8 at the marsh stations ( x̄ = 0.28 ± 0.15 mg L − 1 and x̄ = 0.69 ± 0.35), compared to the inner shelf ( x̄ = 0.16 ± 0.06 mg L − 1 and x̄ = 0.24 ± 0.12) stations, respectively. Low S/V and C/V ratios observed in Terrebonne–Timbalier Bay estuary were likely the result of selective degradation of syringyl and cinnamyl over vanillyl lignin-phenols, and not inputs of woody gymnosperms. A gradient of decreasing S/V ratios along a transect from the upper marshes to the shelf was likely the result of photochemical breakdown of lignin and dilution effects from marine waters near the outer reaches of the estuary. Inputs of photochemically-altered DOC from estuaries such as Terrebonne–Timbalier Bay to the inner Louisiana shelf may provide an additional source of OC for microbial food webs in the northern Gulf of Mexico.

A parametric investigation of the cyclic CO 2 injection process

The influences of important process and reservoir parameters on the cyclic CO 2 injection process were investigated. The parameters examined included gravity segregation, remaining oil saturation, reservoir dip, the presence of a gas cap, and the use of a drive gas. Experiments were performed in Berea Sandstone cores using a light crude oil from the Timbalier Bay field. Gravity segregation, the presence of a gas cap, and a higher remaining oil saturation improved process performance. Oil recovery efficiencies and gas utilization factors were affected by the inclination of the core and the site of injection. Process performance was benefitted when CO 2 was injected into the lower end of a core tilted at an angle of 45 ° or more. A poorer response was obtained when the core was horizontal or when CO 2 was injected into the top of a tilted core. The use of a nitrogen drive (or chase) gas dramatically boosted oil recovery as compared to injection of the same mass of CO 2 alone. Over twice as much oil was recovered by the first cycle injection of CO 2 followed by nitrogen as compared to first cycle injection of that mass of CO 2 alone. The second injection cycle of the drive gas experiment recovered over three times as much oil as recovered by a second cycle injection of that mass of CO 2 alone.

A COOPERATIVE DAMAGE ASSESSMENT: LESSONS FROM THE GREENHILL SPILL1

ABSTRACT Following a September 1992 natural gas and oil well blowout in Timbalier Bay, Louisiana, natural resource trustees took action under the Oil Pollution Act of 1990 (OPA), Clean Water Act (CWA), and the Comprehensive Environmental Response, Compensation, and Liability Act (CERCLA) to restore the natural resources injured by the spill. Trustees appointed by the State of Louisiana and the U.S. Government worked cooperatively with the well owner, Greenhill Petroleum Corporation, in a natural resource damage assessment (NRDA). The resolution of the Greenhill NRDA marks an early success for all parties involved. The process was concluded in December 1993, only 14 months after the spill, when Greenhill and the trustees signed a natural resource restoration agreement. The cooperative assessment and innovative approaches used by the trustees and the well owner resulted in the rapid resolution of the case, rapid environmental restoration, and relatively low assessment costs.

Coastal habitat restoration planning in louisiana: Lessons from the greenhill‐timbalier bay oil spill case

The restoration of marine and coastal habitat has become important because of the frequency of petroleum spills and certain other toxic inputs into the marine environment. Each oil spill must be cleaned up and compensation is sought by federal and state trustees for the restoration of any natural resources injured. This case history details a 1992 well blowout and oil spill in Timbalier Bay, Louisiana, and the assessment and restoration activities that have been associated with the incident. Emphasis is placed on the post‐spill activities to demonstrate the increasing relevance and implementation of habitat restoration efforts under the marine trustee authority of federal, state, and other governments. The Timbalier Bay resource trustees negotiated a restoration‐based administrative settlement to compensate for the injured natural resources. A habitat replacement analysis was conducted to determine the appropriate compensation acreage to be created for the restoration project. The administrative settlemen...

Ghost Fishing by Blue Crab Traps

Ghost fishing by abandoned or lost traps for blue crab Callinectes sapidus was evaluated experimentally in the Timbalier Bay estuary, Louisiana. An average of 12.8 blue crabs per trap were captured by the initial baiting, and an additional 34.9 blue crabs later entered each subsequently unbaited trap; of the total captured, 25.8 died and 21.7 escaped per trap. The turnover of blue crabs was fairly rapid; two-thirds of blue crabs entering the trap either died or escaped within 2 weeks, The number of blue crabs per trap varied seasonally and was a function of the comparative rates of ingress, mortality, and escapement. Small blue crabs (<120 mm carapace width) were more likely to escape, whereas large individuals (>140 mm) tended to remain in the traps and eventually die. Management measures to ameliorate the adverse effect of ghost fishing on the blue crab resource include escape vents and biodegradable panels.

Spawning site selection by spotted seatrout,Cynoscion nebulosus, and black drum,Pogonias cromis, in Louisiana

Spawning site selection by spotted seatrout and black drum was studied by locating drumming aggregations through the use of a hydrophone. From March 1987 to October 1990, 315 sound observations were made to identify and characterize spawning seasons and environmental requirements of both species in the Barataria, Caminada, and eastern Timbalier Bay systems of Louisiana. The sounds produced by the spawning aggregations were identified and verified against known recordings. Spawning was verified on several occasions by capturing and rearing zygotes (eggs) into identifiable larvae. Spotted seatrout formed drumming aggregations from late May to early October at salinities ranging from 7.0 to 25.8 ppt and temperatures from 24.5 to 33.5° C. Black drum formed drumming aggregations between January and April in salinities from 10.0 to 27.0 ppt and temperatures from 15.0 to 24.0°C. Large drumming aggregations of spotted seatrout were located from 1800 to 2400h and from 1800 to 2200h for black drum. Spotted seatrout aggregation size was highly correlated with water temperature and for black drum with dissolved oxygen concentrations. Spawning sites for both species were frequently located in deep moving water between barrier islands as well as in channels in open water where water depth ranged from 3 to 50 m. Spawning site selection depended on a particular range of environmental conditions and spawning locations varied seasonally and yearly depending upon hydrological variation.

The CO2 Huff 'n' Puff Process in a Bottomwater-Drive Reservoir

Summary Two CO2 huff ‘n’ puff projects were conducted in the 4,900-ft [1495-m] Reservoir (BA) Sand Unit [4900' R(BA)SUI, Timbalier Bay field, Louisiana. This reservoir is a bottomwater-drive reservoir with a 26 degrees API [0.9-g/CM3] Oil gravity and 18% primary oil recovery. Before CO2 injection, both project wells were gas lifting more than 1,000 BFPD [160 M3/d fluid] with 99% water cuts. After CO2 injection, the production from each well increased to 200 BOPD [32 m3/d oil]. This paper discusses the CO2 huff ‘n’ puff process, specific reservoir characteristics, and project evaluation. Introduction When properly administered, the CO2 huff ‘n’ puff process provides quick payout with a low capital investment. These are important factors when oil prices are difficult to forecast. Timbalier Bay field was chosen to test the injection process because existing CO2 pipeline and facilities I would reduce the investment. The 4900' R(BA)SU was chosen for the huff ‘n’ puff because of its high residual oil saturation and relatively low API oil gravity. Process Discussion Limited references are available on the CO2 huff ‘n’ puff process despite voluminous publications on CO2 miscible and immiscible recovery. Khatib et al. summarized the evolution of immiscible CO2 injection in light and heavy crudes. Monger and Coma's research work concentrated on applying the CO2 huff ‘n’ puff process on light oils. From their laboratory work on cores at waterflood residual oil saturations and their data base of actual field test results, Monger and Coma concluded that residual oil can be displaced by the cyclic CO2 injection process. Patton et al. and Haskin and Alston have developed the only two correlations for estimating production responses from the CO2 huff ‘n’ puff process. Patton et al. defined two efficiencies to use in evaluating the success of a huff ‘n’ puff project. One efficiency is defined as the ratio of incremental oil produced to CO2 injected. This efficiency should range from 0.5 to 0. 8 STB/Mcf [2.8 × 10(-3) to 4.5 × 10(-3) stock-tank M3/M3], with a value of 1 STB/ Mcf [5.6 × 10(-3) stock-tank M3/M3] representing ideal conditions. The second efficiency is defined as the CO2 injection volume per foot of sand. This efficiency should range from 0.1 to 0.2 MMcf/ft [9.3 × 10(3) to 18.6 × 10(3) M3 /M]. Stright et al. Concluded that the cyclic process "does not appear to be a feasible recovery scheme" in a bottomwater-drive reservoir. When huff ‘n’ puff was applied, their subject reservoir was producing at much lower WOR's than the 4900' R(BA)SU project (2.19 vs. 70). The Timbalier Bay project is notable in that the incremental oil recoveries are greater than those predicted by the Patton et al. method and are recoverable from a bottomwater-drive reservoir with a low sweep efficiency. Throughout the literature is general agreement that the two principal recovery mechanisms in the immiscible CO2-injection process are oil swelling and viscosity reduction. The fractional-flow curves for the 4900' R(BA)SU illustrate how the viscosity-reduction and oil-swelling mechanisms cause production of incremental oil (Fig. 1). The procedure involved in generating these curves is as follows.The water/oil relative permeability is estimated from Stone's correlation.The Buckley-Leverett fractional flow of CO2-free oil is calculated with oil viscosity at reservoir temperature and pressure (Curve 1).The viscosity of CO2-saturated oil is estimated with Emanuel's equation.The new fractional-flow curve is calculated (Curve 2).The fractional-flow curves are overlaid. The viscosity reduction shifts the fractional-flow curve to the right, resulting in a reduced fractional flow of water for a given water saturation. Oil swelling reduces the water saturation, which also results in a decrease in the fractional flow of water. The CO2 swelling effect on the o"/CO2 mixture is estimated with the Peng-Robinson equation of state (PR-EOS). Because of the improvement in fractional-flow conditions, the reservoir is produced to a lower residual oil saturation.

Design, Installation, and Early Operation of the Timbalier Bay S-2B(RA)SU Gravity-Stable, Miscible CO2-Injection Project

Summary This paper reviews the design, installation, and early operation of a gravity-stable, miscible CO2-injection project initiated in April 1984. The purpose of the project is to determine process economics, recoverable reserves, and operational difficulties to evaluate better the potential for fieldwide large-scale CO2 flooding. The results will also help to justify the major investments required to provide pipeline CO2 to the gulf coast oil fields.

Alkanes at the Air-Sea Interface from Offshore Louisiana and Florida

Alkanes at the air-sea interface were analyzed in 118 surface samples collected at five different intervals over a 12-month period from Timbalier Bay (Louisiana), ogfshore Louiisiana, and offshore Florida. The alkanes were characterized by gas chromatography and mass spectrometry. Unexpectedly, methyl branched alkanes ranging in chain length froin C(15) to C(35) and cycloalkanes were frequently the predominant components. This suggests that the alkanes are produced by natural biological sources as well as human activities.

Salt Ridge-Salt Dome Origins in Gulf Coast Area: ABSTRACT

A working hypothesis of salt-ridge, salt-dome formation in the Louisiana Tertiary was formulated in 1957 to explain the observed phenomena along the Caillou Island, Timbalier Bay, Bay Marchand, West Delta Block 30, Venice, and Delta Duck trend: (1) regional down-to-the-north faults of very large stratigraphic throw on the southerly sectors of the domes; (2) a salt, deep-water facies shale ridge connecting Caillou Island, Timbalier Bay, and Bay Marchand at depth; (3) shallow occurrence of older deep-water shales beneath a condensed section on the upthrown sides of down-to-the-north faults; and (4) thick normal facies sections on the north flanks of the domes. Application of results of seismic, bathymetric, and core data from the Gulf of Mexico continental slope gathered and interpreted by Lamont-Texas A&M and Shell groups shows that these phenomena are the results of wavelike salt ridge formation basinward from a prograding shelf edge due to differential loading. Such ridges are present on the continental slope and the major down-to-the-north fault planes are postulated to coincide with the northern faces. The salt ridge grows asymmetrically in cross section, lifting the thinly covered upthrown block and allowing a thicker ponding of sediments on the landward downthrown block. Deep-water shales covering the early ridge roots join the diapiric action of the salt and are confined to the upthrown block until the salt breaks upward through the northward-dipping fault plane. As the salt is further buried by the prograding shelf sediments, it may leave the linear control of the fault and form individual domes with the commonly recognized pattern of shallow salt dome faulting and oil and gas accumulation. End_of_Article - Last_Page 356------------

An Engineering Challenge Development of South Louisiana's Giant Timbalier Bay Field

LIPARI, C.A., JUNIOR MEMBER AIME, GULF OIL CORP., MORGAN CITY, LA. Abstract The Timbalier Bay field, covering 9,500 productive acres of inshore and offshore area, containing 81 productive horizons and some 434 reservoirs ranging in depth from 2,000 to 17,500 ft, presents a challenge to engineers. Reservoir mechanisms of many combinations make it necessary that water flooding, gas injection, attic oil recovery and other recovery methods be examined for possible application in this filed. This paper presents the history and characteristics of the field and the approaches taken by Gulf Oil Corp. in arriving at a system of operation in the coastal waters of South Louisiana. Introduction The operation of an oil field in the coastal area of Louisiana is similar in many ways to operations elsewhere, but there is one significant difference. The operation takes place over a body of water. The logistics of an operation of this type require that all functions be coordinated carefully if the project is to be successful. Throughout 24 years of operating the Timbalier Bay field, Gulf Oil Corp. has employed more efficient equipment as it became available, and the most efficient operating practices known at the time. The purpose of this paper is to convey to the industry the history and the practices followed by Gulf Oil in developing this field in the coastal waters of South Louisiana. Location and General Description The Timbalier Bay oil and gas field is located in, and offshore from, Lafourche Parish, La. (Fig. 1). It is situated approximately 20 miles south of the town of Golden Meadow, 70 miles southeast of Morgan City (the area operational office) and 60 miles southwest of the city of New Orleans. The crest of the structure lies almost directly underneath East Timbalier Island. This low-lying island, averaging about 350-yd wide, is the site of the central Timbalier Bay field camp (Fig. 2) and separates the open waters of the Gulf of Mexico from the shallow Timbalier Bay waters. Access to the field is from the Leeville shore base, through Bayou Lafourche, into Timbalier Bay and the Gulf of Mexico, Presently, there are 410 completion intervals in 277 wells. Daily production is 33,826 STB of oil and 52 MMcf of gas. The productive portion of the field covers approximately 9,500 acres, The present lease arrangement (Fig. 3), within the present productive area of the field, consists of Gulf Oil Corp. as sole owner and operator of Louisiana State Lease "PP" 192, 1772 and 1773, and operator for the joint interest of the Louisiana State Leases 1423, 1483 and the Outer Continental Shelf Lease 0263, Block 21. Union Oil of California operates Louisiana State Leases 3088 and 3324, and Tenneco operates Louisiana State Lease 1369.Surrounding fields are (Fig. 1) Bay Marchand to the cast, Caillou Island to the west, Lake Raccourci to the north and South Timbalier Area Block 54 to the south. JPT P. 127^

A Seasonal Ecological Study of Foraminifera from Timbalier Bay, Louisiana

This study concerns the ecological habits of living Foraminifera from a shallow Louisiana coastal bay during a period of ten months. It is a part of an extensive study undertaken by the Coastal Studies Institute of Louisiana State University to determine the effect of chemical and physical properties of water upon marine life in a large, open bay over an extended period of time. Samples were collected monthly from established locations for the chemical, biological and foraminiferal determinations. Results of the chemical and biological studies will be published by the respective investigators in subsequent papers. The period of time covered by this portion of the study extended from January 1957 to October 1957. Unfortunately, the chemical and biological studies of the bay ended July 1957. Various chemical determinations which were considered pertinent to the study were continued by the investigator throughout the remaining time. Physical influences, such as geomorphology, hydrography and climate, are presented in this paper to help determine exactly what effects each had upon the living Foraminifera of the bay. The chemical data of the bottom waters, presented in Tables 20 to 29, are principally the results of the concurrent chemical study of the bay.

Seasonal Ecological Study of Foraminifera from Timbalier Bay, Louisiana: ABSTRACT

Within the last decade, considerable attention has been directed toward understanding the ecological habits of Foraminifera. This study has ventured deeper than previous ones in an attempt to learn the habits of living Foraminifera in Timbalier Bay, Louisiana, over a period of a year. Ten monthly collections of samples were made from seventeen locations in the bay. Data relating to salinity, temperature, pH, eh, and other chemical and physical properties of the waters were recorded at this time. Upon examination of the samples, it was determined that twenty-three species of Foraminifera could be considered End_Page 1969------------------------------ common in the bay. Two facies zones were recognized within this polyhaline bay by the restriction of certain species to characteristic areas. Reproduction of the Foraminifera appeared to be dependent upon the environmental factors of salinity and temperatures. The use of water chemistry, other than salinity, to explain the reproductive habits of the Foraminifera was unsuccessful. Availability of nutrients is believed to be the principal cause of differences in total populations of living Foraminifera in the bay. These nutrients are probably derived from the land areas and transported around the bay by the normal water flow. Three periods of inflow of these materials into the bay were noted. There has been no comparable foraminiferal study of this bay. A recent foraminiferal study of several bays in Texas (Phleger and Lankford, 1957) is similar, but the periods between collections were longer, and no attempts were made to correlate the Foraminifera with the chemical properties of the bay. Myers (1943) studied the effects of food, substratum, depth, temperature, pH, oxygen tension, turbulence, turbidity, animal associations, parasites, and enemies of a single species, Elphidium crispum, over a period of a year. End_of_Article - Last_Page 1970------------

A Method of Protecting Cements Against the Harmful Effects Of Mud Contamination

Published in Petroleum Transactions, AIME, Volume 210, 1957, pages 148–152. Abstract The laboratory development and field use of oil well cement compositions with high resistance to drilling mud contamination are described. Resistance is obtained by adding a 1-lb mixture composed of three parts paraformaldehyde to two parts sodium chromate tetrahydrate for each sack of cement. This mixture neutralizes the cement-retarding properties of quebracho and other tannins, starch, sodium carboxymethylcellulose, lignite, and monovalent salts of lignosulfonic acid. The retarding properties of calcium lignosulfonate are unaffected. The decontaminating mixture may be used in common cement (designated Type 1 by ASTM specifications, Class A by API Std. 10A) or in a slow set slurry prepared from common cement by addition of calcium lignosulfonate. No changes in slurry viscosities or thickening times are caused by the protecting reagents. The method has been used in 185 field jobs where an improved success ratio has been obtained in plug setting. Introduction Field experience and laboratory investigations have established contamination by drilling mud as a major factor in oil well cement failures. During 1955, 12 attempts were required to set six open-hole cement plugs in the Timbalier Bay field, La. Eighteen to 30 hours elapsed between placing and testing the plugs in preparation for sidetracking operations. Considerations of rig time expense required immediate resetting where soft cement was drilled after a reasonable waiting period. Sea water drilling mud was used in each well and daily additions of thinners, usually lignites, had been required. Sodium carboxymethylcellulose had been added regularly to control fluid loss. The 50 per cent plug failures were attributed primarily to contamination by the mud. Similar experiences can be found in other fields along the Texas and Louisiana coasts where drilling muds normally contain large quantities of organic treating materials.